20-F

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 20-F

(Mark One)

☐
REGISTRATION STATEMENT PURSUANT TO SECTION 12(B) OR (G) OF THE SECURITIES EXCHANGE ACT OF 1934

OR

☒
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended: December 31, 2022

OR

☐
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from __________ to __________.

OR

☐
SHELL COMPANY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Date of event requiring this shell company report __________.

Commission file number: 1-13.396

TRANSPORTADORA DE GAS DEL SUR S.A.

(Exact name of Registrant as specified in its charter)

GAS TRANSPORTER OF THE SOUTH INC.

(Translation of Registrant’s name into English)

Republic of Argentina

(Jurisdiction of incorporation or organization)

Don Bosco 3672

5th Floor

C1206ABF City of Buenos Aires

Argentina

(Address of principal executive offices)

Leandro Pérez Castaño

(54-11)-4865-9077

inversores@tgs.com.ar

Don Bosco 3672

5th Floor

C1206ABF City of Buenos Aires

Argentina

(Name, telephone, email and/or facsimile number and Address of Company contact person)

Securities registered or to be registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
American Depositary Shares (“ADS”), representing Class “B” Shares	TGS	New York Stock Exchange
Class “B” Shares, par value Ps.1.00 per share	n/a	New York Stock Exchange*

*Not for trading, but only in connection with the registration of American Depositary Shares related to the issuer’s American Depositary Receipts (“ADRs”) program, pursuant to the requirements of the Securities and Exchange Commission.

Securities registered or to be registered pursuant to Section 12(g) of the Act:

None

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act:

None

Indicate the number of outstanding shares of each of the issuer’s classes of capital or common stock as of the close of the period covered by the annual report:

Class “A” Shares, par value Ps.1.00 each	405,192,594
Class “B” Shares, par value Ps.1.00 each	347,568,464
Total(1)	752,761,058

⁽¹⁾ Excludes 41,734,225 treasury shares, representing 5.25% of the total shares not deemed outstanding under Argentine law.

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.

Yes
☐ No
☒

If this report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934.

Yes ☐ No
☒

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days.

Yes
☒ No ☐

Indicate by check mark whether the registrant has submitted electronically, every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Yes
☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” and “emerging growth company” in Rule 12b–2 of the Securities Exchange Act of 1934.

Large accelerated filer	☒	Accelerated filer	☐	Non-accelerated filer	☐
				Emerging growth company	☐

If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards† provided pursuant to Section 13(a) of the Securities Exchange Act of 1934. ☐

†The term “new or revised financial accounting standard” refers to any update issued by the Financial Accounting Standards Board to its Accounting Standards Codification after April 5, 2012.

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report.

☒

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements.

☐

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b)

☐

Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:

U.S. GAAP ☐ International Financial Reporting Standards as issued by the International Accounting Standards Board ☒ Other ☐

If “Other” has been checked in response to the previous question, indicate by check mark which financial statement item the registrant has elected to follow.

Item 17 ☐ Item 18 ☐

If this is an Annual Report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Securities Exchange Act of 1934).

Yes ☐ No ☒

TABLE OF CONTENTS

PRESENTATION OF FINANCIAL AND OTHER INFORMATION			I
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS			V
PART I			1
	Item 1.	Identity of Directors, Senior Management and Advisers	1
	Item 2.	Offer Statistics and Expected Timetable	1
	Item 3.	Key Information	1
	Item 4.	Our Information	52
	Item 4A.	Unresolved Staff Comments	114
	Item 5.	Operating and Financial Review and Prospects	115
	Item 6.	Directors, Senior Management and Employees	148
	Item 7.	Major Shareholders and Related Party Transactions	162
	Item 8.	Financial Information	169
	Item 9.	The Offer and Listing	175
	Item 10.	Additional Information	178
	Item 11.	Quantitative and Qualitative Disclosures About Market Risk	201
	Item 12.	Description Seof curities Other than Equity Securities	201
PART II			203
	Item 13.	Defaults, Dividend Arrearages and Delinquencies	203
	Item 14.	Material Modifications to the Rights of Security Holders and Use of Proceeds	203
	Item 15.	Controls and Procedures.	203
	Item 16.	[Reserved]	204
	Item 16A.	Audit Committee Financial Expert	204
	Item 16B.	Code of Ethics	204
	Item 16C.	Principal Accountant Fees and Services	204
	Item 16D.	Exemptions from the Listing Standards for Audit Committees	205
	Item 16E.	Purchases of Registered Equity Securities of the Issuer by the Issuer and Affiliated Purchasers	205
	Item 16F.	Change in Registrant’s Certifying Accountant	207
	Item 16G.	Corporate Governance	207
	Item 16H.	Mine Safety Disclosure	209
	Item 16I.	Disclosure Regarding Foreign Jurisdictions that Prevent Inspection	209
	Item 16J	Insider Trading Policies	210
PART III			210
	Item 17.	Financial Statements	210
	Item 18.	Financial Statements	210
	Item 19.	Exhibits	210

PRESENTATION OF FINANCIAL AND OTHER INFORMATION

Certain Defined Terms

In this annual report on Form 20-F (“Annual Report”), unless otherwise indicated or the context requires otherwise: (i) references to “we,” “us,” “our” and the “Company” mean Transportadora de Gas del Sur S.A. (“tgs”) and its consolidated subsidiaries, Telcosur S.A. (“Telcosur”), TGSLatam Energía S.A. (“TGSLatam”) and CTG Energía S.A.U. (“CTG”), (ii) references to “Argentina” are to the Republic of Argentina, (iii) references to the “United States” or “U.S.” are to the United States of America, (iv) references to “pesos” or “Ps.” are to Argentine pesos, the legal currency of Argentina, (v) references to “U.S. dollars,” “dollars” or “U.S.$” are to United States dollars, the legal currency of the United States, (vi) a “billion” is a thousand million, (vii) references to “cf” are to cubic feet, (viii) references to “MMcf” are to millions of cubic feet, (ix) references to “Bcf” are to billions of cubic feet, (x) references to “m3” are to cubic meters, (xi) references to “d” are to days, and (xii) references to “HP” are to horsepower.

Financial Statements and Basis of Preparation

We maintain our financial books and records and publish our consolidated Financial Statements (as defined below) in pesos, which is our functional currency. This Annual Report includes our audited consolidated statements of financial position as of December 31, 2022 and 2021, and our audited consolidated statements of comprehensive income, changes in equity and cash flows, and the related explanatory notes for the years ended December 31, 2022, 2021 and 2020 (our “Financial Statements”). Our Financial Statements have been prepared in accordance with International Financial Reporting Standards (“IFRS”) as issued by the International Accounting Standards Board (“IASB”) and as in effect on the date of preparation of the Financial Statements. IFRS have been adopted by the Federación Argentina de Consejos Profesionales de Ciencias Económicas (“FACPCE”) as its professional accounting standards and are required to be adopted by certain public companies in Argentina (entidades incluidas en el régimen de oferta pública de la Ley de Mercado de Capitales) pursuant to the rules of the Comisión Nacional de Valores (“CNV”), compiled under General Resolution No. 622/2013 (as amended by General Resolution No. 668/2016 and as further amended, the “CNV Rules”).

At our shareholders’ meeting held on April 26, 2017, as a result of a proposal by our controlling shareholder, Compañía de Inversiones de Energía S.A. (“CIESA”), our shareholders voted in favor of having a joint audit on our consolidated financial statements commencing with fiscal year ended December 31, 2017, even though there is currently no legal requirement in Argentina for a joint audit. As a result, our Financial Statements were jointly audited by Price Waterhouse & Co. S.R.L., Buenos Aires, Argentina (“PwC”), member firm of PricewaterhouseCoopers International Limited, and Pistrelli, Henry Martin y Asociados S.R.L. (“EY”), member firm of Ernst & Young Global Limited. The joint report of PwC and EY, dated April 25, 2023, is included elsewhere in this Annual Report. Each of PwC and EY is an independent registered public accounting firm, as stated in the joint report appearing herein.

International Accounting Standard 29 (“IAS 29”) “Financial reporting in hyperinflationary economies” requires that the financial statements of an entity whose functional currency is one of a hyperinflationary economy be expressed in terms of the current unit of measurement at the closing date of the reporting period, regardless of whether such financial statements are based on the historical cost method or the current cost method. This requirement also comprises the restatement of comparative information of the financial statements to be presented in the current currency as of December 31, 2022, without modifying the statutory decisions made based on the financial information corresponding to those fiscal years.

i

IAS 29 describes characteristics that may indicate that an economy is hyperinflationary. However, it states that it is a matter of judgement by management when restatement of financial statements becomes necessary. Among other factors, an economy is “hyperinflationary” in accordance with IAS 29 when it has a cumulative inflation rate over three years that approaches, or exceeds, 100%, also taking into consideration other qualitative factors related to the macroeconomic environment.

The IASB does not identify specific economies that satisfy the requirements to be deemed hyperinflationary. The International Practices Task Force (“IPTF”) of the Center for Audit Quality monitors the status of “highly inflationary” countries. The criteria of IPTF for identifying such countries are similar to those for identifying “hyperinflationary economies” under IAS 29. From time to time, the IPTF issues reports of its discussions with the staff of the Securities and Exchange Commission (“SEC”) on the IPTF’s recommendations of which countries should be considered highly inflationary, and which countries are on the IPTF’s inflation “watch list.” The IPTF’s discussion document for its November 9, 2022 meeting states that in the view of the IPTF, Argentina had a three-year cumulative inflation rate exceeding 100%.

Inflation in Argentina significantly increased during 2022, 2021 and 2020, which resulted in an accumulated inflation rate for each of the three-year periods ended December 31, 2022, 2021 and 2020, in excess of 100%. In addition, the rest of the indicators do not contradict the conclusion that Argentina should be considered a hyperinflationary economy for accounting purposes. As a result, our management considers that there is sufficient evidence to conclude that Argentina is a hyperinflationary economy in terms of IAS 29, effective as from July 1, 2018.

The Financial Statements and the other financial information included in this Annual Report for all the periods reported are presented on the basis of constant pesos as of December 31, 2022 (“Current Currency”). Thus, our audited consolidated statements of financial position as of December 31, 2021, and our audited consolidated statements of comprehensive income, changes in equity and cash flows, and the related explanatory notes for each of the years ended December 31, 2021 and 2020, included elsewhere in this Annual Report have been restated in accordance with IAS 29 for comparative purposes from the original figures reported and supersede any previously disclosed consolidated financial statements relating to such periods.

In analyzing the provisions of IAS 29, our management used the inflation rates stated in the official statistics published by the Instituto Nacional de Estadística y Censos (“INDEC”), similar to the criteria adopted by the accounting profession and corporate regulatory bodies in Argentina. In order to restate the financial statements referred in the immediately preceding paragraph, the CNV has established that the series of indexes to be used for the application of IAS 29 is determined by the FACPCE. This series of indexes combines the National Consumer Price Index (“CPI”) as of January 2020 (base month December 2019) with the Domestic Wholesale Price Index (“WPI”), both published by INDEC until that date. According to information from FACPCE, inflation was 94.5%, 50.9%, and 36.1% in the years ended December 31, 2022, 2021 and 2020, respectively.

For more information, see note 4(d) to the Financial Statements and “Item 5. Operating and Financial Review and Prospects—A. Operating Results—Factors Affecting Our Consolidated Results of Operations.” Also, see “Item 3. Key Information—D. Risk Factors—Risks Relating to Argentina—High levels of inflation could negatively affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.”

ii

Currency

Solely for the convenience of the reader, certain amounts presented in pesos in this Annual Report as of and for the year ended December 31, 2022, have been converted into U.S. dollars at specified exchange rates. Unless otherwise specified, all exchange rate information contained in this Annual Report has been derived from information published by Banco de la Nación Argentina (“Banco Nación”) on December 31, 2022, without any independent verification by us. As a result of fluctuations in the peso/U.S. dollar exchange rate, the exchange rate at such date may not be indicative of current or future exchange rates. Such fluctuations may affect the U.S. dollar equivalent of peso amounts included in this Annual Report. Consequently, these translations should not be construed as a representation that the peso amounts represent, or have been, or could be converted, into, U.S. dollars at that or any other rate.

Fluctuations in the exchange rate between pesos and U.S. dollars would affect the U.S. dollar equivalent of the peso price of our Class “B” shares, par value Ps.1 each (the “Class B Shares”), on the Buenos Aires Stock Exchange (Bolsas y Mercados Argentinos (“BYMA”)) and, as a result, the market price of our American Depositary Shares (“ADSs”) on the New York Stock Exchange (“NYSE”) as well.

Historically, Argentina has been subject to several restrictions imposed on the foreign exchange market. In the recent years, the Central Bank of the Republic of Argentina (Banco Central de la República Argentina or the “BCRA”) issued several communications which introduced several changes to the then existing foreign exchange control regime. For additional information, see “Item 10. Additional Information—D. Exchange Controls.”

The following table sets forth, for the periods indicated, high, low, average and period-end exchange rates between the peso and the U.S. dollar, as reported by Banco Nación. The Federal Reserve Bank of New York does not publish a buying rate for the peso. The average rate is calculated by using the average of Banco Nación reported exchange rates on each day during the relevant monthly period and on the last day of each month during the relevant annual period.

	Pesos per U.S. dollar
	High		Low		Average		Period end
Most recent six months:
November 2022		167.28		157.28		162.12		167.28
December 2022		177.16		167.72		172.90		177.16
January 2023		187.00		178.15		182.24		187.00
February 2023		197.15		187.29		191.89		197.15
March 2023		209.10		197.57		203.11		209.01
Year ended December 31,
2018		41.25		18.41		28.13		37.70
2019		60.40		36.90		48.23		59.89
2020		84.15		59.81		70.78		84.15
2021		102.72		84.70		95.16		102.72
2022		177.16		103.00		130.81		177.16

iii

Our results of operations and financial condition are highly sensitive to changes in the peso-U.S. dollar exchange rate because a significant portion of our revenues (65% of our total consolidated revenues from sales for the year ended December 31, 2022), most of our capital expenditures, almost all of our debt obligations and the cost of natural gas used in our Liquids business are denominated in U.S. dollars, but substantially all of our assets are located in Argentina, and our functional currency is the peso.

Currency fluctuations would also affect the U.S. dollar amounts received by holders of our ADSs upon conversion (by us or by Citibank N.A. (the “Depositary”), pursuant to the deposit agreement for the issuance of the ADSs entered into between the Depositary and us (the “Deposit Agreement”)) of the cash dividends paid in pesos on the underlying Class “B” Shares.

Rounding

Certain figures included in this Annual Report have been rounded for ease of presentation. Percentage figures included in this Annual Report have not, in all cases, been calculated on the basis of such rounded figures but on the basis of such amounts prior to rounding. For this reason, percentage amounts in this Annual Report may vary from those obtained by performing the same calculations using the figures in our Financial Statements. Certain numerical figures shown as totals in some tables may not be an arithmetic aggregation of the figures that preceded them due to rounding.

Available Information

The SEC maintains an internet site (http://www.sec.gov) that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC. Our telephone number is (54-11) 4865-9050, and our principal executive offices are located at Don Bosco 3672, 5th Floor, C1206ABF City of Buenos Aires, Argentina. Our internet address is www.tgs.com.ar. This URL is intended to be an inactive textual reference only. It is not intended to be an active hyperlink to our website. The information included in our website or which may be accessed through our website is not part of this Annual Report, is not incorporated by reference herein or otherwise and should not be relied upon in determining whether to make an investment in any securities issued by us.

iv

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING STATEMENTS

Some of the information in this Annual Report, including information incorporated by reference herein, may constitute estimates and forward-looking statements within the meaning of Section 27A of the U.S. Securities Act of 1933 (the “Securities Act”) and Section 21E of the U.S. Securities Exchange Act of 1934, as amended (the “Exchange Act”). These estimates and forward-looking statements can be identified by the use of forward-looking terminology such as “anticipate,” “believe,” “can,” “continue,” “estimate,” “expect,” “goal,” “intend,” “may,” “plan” “potential,” “predict,” “projection,” “should,” “will,” “will likely result,” “would” or other similar words. These estimates and statements appear in a number of places in this Annual Report and include statements regarding our intent, belief or current expectations, and those of our officers, with respect to (among other things) our business, financial condition and results of operations. Although we believe that these estimates and forward-looking statements are based upon reasonable assumptions, they are subject to several risks and uncertainties and are based on information available to us as of the date of this Annual Report.

When considering forward-looking statements, you should keep in mind the factors described in “Item 3. Key Information—D. Risk Factors” and other cautionary statements appearing in “Item 5. Operating and Financial Review and Prospects.” These factors and statements, as well as other statements contained herein, describe circumstances that could cause actual results to differ materially from those expressed in or implied by any forward-looking statement.

Forward-looking statements include, but are not limited to, the following:

• statements regarding changes in general economic, business, political or other conditions in Argentina and globally, including changes from actions taken by the Argentine government (the “Government”) and changes due to natural and human-induced disasters (including the COVID-19 virus (“COVID”) pandemic and the invasion of Ukraine by Russia), and the impact of the foregoing;

• estimates relating to future energy demand (including demand for fossil fuels), tariffs and volumes for our natural gas transportation services and future prices and volumes for our natural gas liquid products such as propane and butane (also referred to as liquid petroleum gas or “LPG”), ethane and natural gasoline (collectively “Liquids”) and for products and services provided in the Other Services business segment;

• statements regarding future political developments in Argentina and future developments regarding the license granted to us by Government to provide natural gas transportation services through the exclusive use of the southern natural gas transportation system in Argentina (“License”), the impact of the adoption of the new revised scheme of tariffs resulting from the renegotiation process of our License with the Government, regulatory actions by Ente Nacional Regulador del Gas (“ENARGAS”) and other agencies of the Government, the legal framework established by the Federal Energy Bureau and any other applicable governmental authority that may affect us and our business;

• with our employees in Argentina;

v

• statements and estimates regarding future pipeline expansion and other projects and the cost of, or return to us from, any such expansion or projects;

• estimates of our future level of capital expenditures and delays in such capital expenditures, including those required by ENARGAS or other governmental authorities for the expansion of our pipeline system or other purposes, and unscheduled and unexpected expenditures for the repair and maintenance of our fixed or capital assets;

• statements regarding the ability of companies engaged in the upstream business in the region where we operate to identify drilling locations and prospects for future drilling opportunities, and drill and develop such locations (such as the Vaca Muerta formation), as well as the Government’s regulations and policies affecting such companies and projects; and

• the risk factors discussed under “Item 3. Key Information—D. Risk Factors.”

Estimates and forward-looking statements speak only as of the date of this Annual Report and we do not undertake any obligation to update any forward-looking statement or other information contained in this Annual Report to reflect events or circumstances occurring after the date of this Annual Report or to reflect the occurrence of unanticipated events. Additional factors affecting our business emerge from time to time and it is not possible for us to predict all of those factors, nor can we assess the impact of all such factors on our business, operations or financial condition, or the extent to which any factors, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statement. Estimates and forward-looking statements involve risks and uncertainties and do not guarantee future performance, as actual results or developments may be substantially different from the expectations described in the forward-looking statements. In light of the risks and uncertainties described above, the events referred to in the estimates and forward-looking statements included in this Annual Report may or may not occur, and our business performance, financial condition and results of operations may differ materially from those expressed in our estimates and forward-looking statements, due to factors that include but are not limited to those mentioned above. Investors are warned not to place undue reliance on any estimates or forward-looking statements in making any investment decision.

vi

PART I

Item 1. Identity of Directors, Senior Management and Advisers

Not applicable.

Item 2. Offer Statistics and Expected Timetable

Not applicable.

Item 3. Key Information

A. [Reserved]

B. Capitalization and Indebtedness

Not applicable.

C. Reasons for the Offer and Use of Proceeds

Not applicable.

D. Risk Factors

You should carefully consider the following risks and uncertainties, and any other information appearing elsewhere in this Annual Report. The risks and uncertainties described below are intended to highlight risks and uncertainties that are specific to us. Additional risks and uncertainties, including those generally affecting Argentina and the industry in which we operate, risks and uncertainties that we currently consider immaterial or risks and uncertainties generally applicable to similar companies in Argentina may also impair our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

The information in this Risk Factors section includes forward-looking statements that involve risks and uncertainties. Our actual results could differ materially from those anticipated in these forward-looking statements as a result of numerous factors, including those described in “Cautionary Statement Regarding Forward-Looking Statements” above.

The following summarizes some, but not all, of the risks provided below. The following summary of material risk factors could materially and adversely affect our business, financial condition and results of operation, and our ability to meet our financial obligations. Consequently, such risk factors may cause historical results to differ materially from any results projected, forecasted, estimated or budgeted by us in our forward-looking statements. Please carefully consider all of the information discussed in this “Item 3. Key Information—D. Risk Factors” in this Annual Report for a more thorough description of these and other risks:

• Risks Relating to Our Business

‒ Failure or delay in the implementation of tariff increases could have a material adverse effect on our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

‒ Under the Decree 1020 tariffs were frozen until the new RTI concludes. Since that moment we have received only one tariff increase since March 1, 2022 amounting to 60%. "Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Regulatory Framework —Tarrif situation."

‒ Our operations are subject to extensive regulation.

‒ Failure to maintain our relationships with labor unions may have an adverse effect on our business, financial condition, results of operations and prospects.

‒ Our regulated business is dependent on our ability to maintain our License, which is subject to revocation under some circumstances.

‒ Our creditors may not be able to enforce their claims against us in Argentina.

‒ The Government’s strategies, measures and programs with respect to the natural gas transportation industry could materially adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

‒ A significant portion of our revenues is generated under natural gas transportation contracts that must be renegotiated and/or extended periodically.

‒ Our business may require substantial capital expenditures for ongoing maintenance requirements and the expansion of our installed transportation capacity; we could be unable to make such expenditures due to the lack of financing.

‒ Our Liquids production depends on the natural gas that arrives at the Cerri Complex through three main pipelines from the Neuquina, Austral and San Jorge natural gas basins. The flow and heating value of this natural gas are subject to risks that could materially adversely affect our Liquids and midstream business segment.

‒ Measures taken by the Government may have an adverse effect on the supply of natural gas to the Cerri Complex and the margins we are able to obtain from our Liquids business, which may adversely affect the results in our Liquids Production and Commercialization segment and, as a result, our overall business and results of operations.

‒ Fluctuations in market prices and the enactment of new taxes or regulations limiting the sales price of LPG and natural gasoline may affect our Liquids business.

‒ Our business, financial condition and results of operations have been, and may continue to be, adversely affected by the ongoing COVID pandemic and the emergence of a pandemic-level disease or threat to public health.

‒ Our ethane sales depend on the capacity of PBB, as the sole purchaser of our ethane production.

‒ The affirmative and restrictive covenants in our currently outstanding indebtedness could adversely restrict our financial and operating flexibility and subject us to other risks.

‒ Our insurance policies may not fully cover damage or we may not be able to obtain insurance against certain risks.

‒ Changes in the interpretation by the courts of labor laws that tend to favor employees could adversely affect our business, results operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

2

‒ We may be exposed to risks related to litigation and administrative proceedings that could materially and adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations in the event of an unfavorable ruling.

‒ Our operations are subject to environmental, occupational health and safety regulations.

‒ Our operations could cause environmental risks and any change in environmental laws could increase our operating costs.

‒ We may face competition.

‒ Downgrades in our credit ratings could have negative effects on our funding costs and business operations.

‒ Our business has become dependent on digital technologies to conduct day-to-day operations and we may be subject to cyberattacks or other risks related to new technologies.

‒ Our natural gas transportation systems and processing facilities are subject to the risk of mechanical or electrical failures and any resulting unavailability may affect our ability to fulfill our contractual and other commitments and thus adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

‒ Our business is subject to risks arising from natural disasters, catastrophic accidents and terrorist attacks.

‒ We are subject to anti-trust, anti-corruption, anti-bribery and anti-money laundering laws. Failure to comply with these laws could result in penalties, which could harm our reputation and have an adverse effect on our business.

‒ Our ability to operate our business may suffer if we are unable to retain our employees or attract other skilled employees or contractors.

‒ Climate change could impact our operating results, access to capital and strategy.

‒ Our activities are subject to social and reputational risks, including the potential for protests by members of the local communities.

‒ The failure of any bank in which we deposit our funds could have an adverse effect on our financial condition.

• Risks Relating to Argentina

‒ Argentina’s public debt may not be sustainable in the near future.

‒ Argentina’s fiscal situation could limit the country’s access to the capital market and adversely affect the Argentine economy.

‒ Certain risks inherent to any investment in a company operating in an emerging market such as Argentina.

3

‒ Economic volatility in Argentina has adversely affected and may continue to adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

‒ The ongoing political instability in Argentina may adversely affect the Argentine economy.

‒ The Solidarity Law and the measures that the new administration has implemented could adversely affect our results of operations and financial condition.

‒ Public health threats could have an adverse effect on the Argentine economy and on our business, financial condition or results of operations.

‒ High levels of inflation could negatively affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

‒ Restrictions on transfers of foreign currency and the repatriation of capital from Argentina may impair our ability to pay dividends or imports and investors may face restrictions on their ability collect capital and interest payments in connection with corporate bonds issued by Argentine companies.

‒ Fluctuations in the value of the peso may also adversely affect the Argentine economy, our financial condition and results of operations.

‒ The impossibility of addressing the actual and potential risks of institutional deterioration and corruption, the economy and the financial situation of Argentina has been affected negatively and could continue to be.

‒ Government intervention in the Argentine economy could adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

‒ The Argentine economy may be adversely affected by economic developments in other markets and by more general effects, which could have a material adverse effect on Argentina’s economic growth.

‒ Argentina’s past default and litigation with holdout bondholders may limit our ability to access international markets.

‒ A sustained deterioration in the terms of trade given a decline in the global prices for Argentina’s main commodity exports or an increase in the global prices for Argentina’s main commodity imports, as well as adverse weather conditions affecting the production of Argentina’s main commodity exports, could have an adverse effect on Argentina’s economic growth.

‒ Further downgrades in the credit rating or rating outlook of Argentina could impact the rating of our securities or adversely affect the market price of our securities.

‒ The Argentine government may mandate salary increases for private sector employees, which would increase our operating costs.

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‒ Argentine corporations may be restricted from making payments in foreign currencies or from importing certain products.

‒ Argentina’s ability to obtain financing from international markets could be limited, which may impair its ability to implement reforms and foster economic growth and, consequently, affect our business, results of our operations and growth prospects.

‒ The conflict between Russia and Ukraine could adversely affect the global economy, the Argentine economy and our operational results and financial condition.

‒ We continue operating in a period of economic uncertainty and capital markets disruption, which has been significantly impacted by geopolitical instability since the ongoing military conflict between Russia and Ukraine, poor global economic performance, a potential recession looming in the U.S. and Europe and China showing weak growth.

• Risks Relating to Our Shares and ADSs

‒ shareholders outside Argentina may face additional investment risk from currency exchange rate fluctuations in connection with their holding of our shares or ADSs represented by ADRs. Exchange controls imposed by the Government may limit our ability to make payments to the Depositary in U.S. dollars, and thereby limit ADR holders´ability to receive cash dividends in U.S. dollars.

‒ Our principal shareholders exercise significant control over matters affecting us, and may have interests that differ from those of our other shareholders.

‒ Sales of a substantial number of shares could decrease the market prices of our shares and the ADRs.

‒ Under Argentine law, shareholder rights may be fewer or less well defined than in other jurisdictions.

‒ As a foreign private issuer we are exempt from certain rules that apply to domestic U.S. issuers.

‒ Changes in Argentine tax laws may adversely affect the tax treatment of our Class B Shares or ADSs.

‒ Holders of ADRs may be unable to exercise voting rights with respect to our Class B Shares underlying the ADRs at our shareholders’ meetings.

‒ Holders of ADRs may be unable to exercise preemptive, accretion or other rights with respect to the Class B shares underlying the ADSs.

‒ The NYSE and/or BYMA may suspend trading and/or delist our ADSs and common shares, respectively, upon occurrence of certain events relating to our financial situation.

‒ The price of our Class B Shares and the ADSs may fluctuate substantially, and your investment may decline in value; and

‒ The relative volatility and illiquidity of the Argentine securities markets may substantially limit the ability to sell the Class B Shares underlying the ADSs on the BYMA at the price and time desired by the shareholder.

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Risks Relating to Our Business

Failure or delay in the implementation of tariff increases could have a material adverse effect on our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

All of our net revenues from the Natural Gas Transportation public service (which represented 25% of total revenues during 2022) are attributable to contracts, which are subject to Government regulation. Prior to the enactment of the Public Emergency Law and Foreign Exchange System Reform Law No. 25,561 (the “Public Emergency Law”), our tariffs were stated in U.S. dollars, adjusted on a semiannual basis by reference to the U.S. Producer Price Index (“PPI”), and further adjusted every five years, based on the efficiency of, and investments in, our gas transportation business. The Public Emergency Law, however, eliminated tariff indexation, and public service tariffs were converted into pesos and fixed at an exchange rate of Ps.1.00 per US$1.00, even though the peso was devaluating significantly against the U.S. dollar.

Sustained inflation in Argentina since 2002, without any corresponding increase in our natural gas transportation tariffs until recently, has adversely affected, and continued inflation would continue to adversely affect, our Natural Gas Transportation revenues and financial condition. During the last few years, we have monitored our operating costs in order to minimize the impact of the insufficient adjustment of our tariffs on our activities. These measures have had no negative impact on the reliability and efficiency tasks carried out on the pipeline system.

On March 30, 2017, ENARGAS issued Resolution No. 4362/2017 (“Resolution 4362”), which approved a staged tariff increase which contemplates an aggregate transportation tariff increase of 214.2% and an aggregate access and use charge (“CAU”) increase of 37%. This staged increase is structured to provide the same economic benefits to us as if the increases had been fully effective on April 1, 2017. Pursuant to this resolution, we must also execute a capital expenditures program for a five-year period (from April 1, 2017, to March 31, 2022), which contemplates investments of Ps.6,786 million (in nominal value on December 31, 2016) to improve the operation and maintenance of the pipeline system (the “Five-Year Plan”). In addition, Resolution 4362 contemplates a non-automatic semiannual adjustment mechanism for the natural gas transportation tariff to reflect changes in WPI, which must be approved by ENARGAS evaluating the evolution of the economic circumstances.

On March 27, 2018, through Decree No. 250/2018 (“Decree 250”), the Executive Branch ratified the tariff structure under Resolution 4362, following the approval of several governmental authorities, including the Argentine Congress. Decree 250 concluded the renegotiation process of our License with the Government, which lasted more than 17 years. After the conclusion of the RTI mentioned above, we received the semiannual tariff increase corresponding for the period August 2018–February 2019 beginning on April 2019.

As a consequence of Argentina’s economic condition, and together with other measures taken by the Government, on September 3, 2019, the Secretary of Hydrocarbon Resources (“SHR”) (formerly the Federal Energy Bureau) issued Resolution No. 521/2019 (“Resolution 521”), which defers the subsequent semiannual adjustment.

Under the Decree 1020 tariffs were frozen until the new RTI concludes. Since that moment we have received only one tariff increase since March 1, 2022 amounting to 60%. “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Regulatory Framework—Tariff situation.”

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On December 6, 2022, by means of Decree No. 815/2022 (“Decree 815”), the term for the completion of the RTI established in Decree 1020 was extended until December 18, 2023. Within this framework, on January 4, 2023, a public hearing was held to consider a new transitory tariff adjustment for the public natural gas transportation service.

On March 15, 2023 ENARGAS submitted a proposal to us for an addendum to the RTI.

On March 16, 2023, our Board of Directors approved the proposed addendum to the renegotiation transitory agreement (the “2023 Transition Agreement”) sent by ENARGAS. As of the date of this Annual Report the Executive Branch has not ratified the 2023 transition agreement.

The 2023 Transition Agreement has similar conditions to the 2022 Transition Agreement. The 2023 Transition Agreement includes:

- A transitional tariff increase of 95% on the natural gas transportation tariff and the Access and Use Charge.

- With prior authorization from the Ministry of Economy, we are allowed to distribute dividends and to directly or indirectly prepay financial and commercial debts contracted with shareholders, which were previously prohibited by the 2022 Transition 9Agreement.

In the past, we have suffered from our inability to receive tariff increases, which meant the deterioration of our financial and economic condition. Also, we have received insufficient tariff increases to compensate for the increases in our operating costs due to inflation. For additional information about the prior RTI processes and failure by ENARGAS to increase tariffs, and the status of the ongoing RTI see “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Regulatory Framework—Tariff situation.”

We cannot assure you that the current negotiations with the Government will provide us with a tariff schedule that permits us to compensate the increases in our operating costs. Failure by the Government to timely comply with agreements resulting from the new RTI process could negatively affect our results of operations and financial condition.

Moreover, as of the date of this Annual Report, we are unable to predict which permanent measures will be taken by the Government in connection with the tariff system, or if such system will be amended, adversely affecting our financial situation and our results of operations.

Further, we cannot assure you that the current negotiations with the Government under the framework of the Solidarity Law will provide us with a tariff schedule that permits us to compensate the increases in our operating costs. Failure by the Government to timely comply with agreements resulting from the RTI process could negatively affect our results of operations and financial condition.

In addition, we cannot predict whether additional operating restrictions or mandatory investments could be imposed on us in the future nor the outcome from the renegotiation process of the current RTI stated by the Solidarity Law. If such outcome is adverse to us, our results of operations and financial condition could be negatively affected.

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Our operations are subject to extensive regulation.

The Argentine oil and gas industry is subject to extensive government regulation and control. As a result, our business is to a large extent dependent upon regulatory and political conditions prevailing in Argentina and our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations may be adversely affected by regulatory and political changes in Argentina. Therefore, we face risks and challenges relating to government regulation and control of the energy sector, including those set forth below and elsewhere in these risk factors:

• limitations on our ability to increase prices or to reflect the effects of higher domestic taxes, increases in operating costs or increases in international prices of natural gas and other hydrocarbon fuels and exchange rate fluctuations on our domestic prices;

• risks in connection with the former and current incentive programs established by the Government for the oil and gas industry, such as the natural gas additional injection stimulus program and cash collection of balances with the Government;

• legislation and regulatory initiatives relating to hydraulic stimulation and other drilling activities for non-conventional oil and gas hydrocarbons, which could increase our cost of doing business or cause delays and adversely affect our operations; and

• the implementation or imposition of stricter quality requirements for hydrocarbon products in Argentina.

In recent years, the Government has made certain changes in regulations and policies governing the energy sector to give absolute priority to domestic supply at stable prices in order to sustain economic recovery. As a result of the above-mentioned changes, for example, on days during which a gas shortage occurs, exports of natural gas (which are also affected by other government curtailment orders) and the provision of gas supplies to industries, electricity generation plants and service stations selling compressed natural gas are interrupted to prioritize residential consumers at lower prices. The Expropriation Law of Argentina has declared the achievement of self-sufficiency in the supply of hydrocarbons, as well as in the exploitation, industrialization, transportation and sale of hydrocarbons, is in the national public interest and a priority for Argentina. In addition, its stated goal is to guarantee socially equitable economic development, the creation of jobs, the increase of the competitiveness of various economic sectors and the equitable and sustainable growth of the Argentine provinces and regions. We cannot assure you that these and other changes in applicable laws and regulations, or adverse judicial or administrative interpretations of such laws and regulations, will not adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

Failure to maintain our relationships with labor unions may have an adverse effect on our business, financial condition, results of operations and prospects.

A significant portion of our workforce is represented by labor unions, and most of our non-unionized employees have the same employment benefits as unionized employees. While we believe we have enjoyed satisfactory relationships with all the labor organizations that represent our associates, and we believe our relationships with labor organizations will continue to be satisfactory, labor-related disputes may still arise. Labor lawsuits are common in the energy sector in Argentina, and industry-wide organized actions by unionized employees in the industry, such as blockages in the access to facilities and route cuts have occurred in the past. We have suffered interruptions as a result of our employees joining such organized activities. We cannot assure you that future business interruptions resulting from strikes and other organized activities by our employees would not have a significant adverse effect on our business, financial condition, results of operations and prospects.

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The collective bargaining agreements with our unions are valid for one year. Currently, we have a collective bargaining agreement in effect for the period from April 2023 to April 2024.

However, we cannot assure you that we will not suffer business interruptions or strikes in the future as a result of collective actions by our employees. We have insurance that covers terrorism and organized actions against our assets, among other items, for a total insured amount of US$50,000,000 with a deductible per event of US$500,000, but we cannot assure you that our insurance coverage will be sufficient to cover damages and losses caused by the organized actions of our employees.

In addition, in the past, the Government has enacted laws and regulations forcing private companies to maintain certain wage levels and to provide additional benefits to their employees. We cannot assure you that in the future the Government will not increase wages or require additional benefits for workers or employees or that unions will not pressure the Government to demand such measures. All wage increases, as well as any additional benefits, could result in increased costs and adversely affect our results of operations.

Our regulated business is dependent on our ability to maintain our License, which is subject to revocation under some circumstances.

We conduct our Natural Gas Transportation business pursuant to the License, which authorizes us to provide natural gas transportation services through the exclusive use of the southern natural gas transportation system in Argentina. Our License may be revoked in certain circumstances based on the recommendation of ENARGAS. Revocation of our license would require an administrative proceeding, which would be subject to judicial review. Reasons for which our License may be revoked include:

• repeated failure to comply with the obligations of our License and failure to remedy a significant breach of an obligation in accordance with specified procedures;

• total or partial interruption of service for reasons attributable to us that affects transportation capacity during the periods stipulated in our License;

• sale, assignment or transfer of our essential assets or the placing of encumbrances thereon without ENARGAS’s prior authorization, unless such encumbrances serve to finance extensions and improvements to the gas pipeline system;

• our bankruptcy, dissolution or liquidation;

• cessation and abandonment of the provision of the licensed service, an attempt to assign or unilaterally transfer our License in full or in part without the prior authorization of ENARGAS, or relinquishing our License, other than in the cases permitted therein; and

• delegation of the functions granted in such License without the prior authorization of ENARGAS, or the termination of such License without regulatory approval of a license.

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If our License were revoked, we would be required to cease providing natural gas transportation services. The impact of a loss of our License on our business, financial condition and results of operations would be material and adverse. Additionally, certain changes to the License could result in a default under our outstanding debt instruments.

Our creditors may not be able to enforce their claims against us in Argentina.

We are a stock corporation with limited liability (sociedad anónima), incorporated and organized under the laws of Argentina. Substantially all of our assets are located in Argentina.

Under Argentine law, foreign judgments may be enforced by Argentine courts, provided that the requirements of Articles 517 through 519 of the Federal Code of Civil and Commercial Procedure are met. Foreign judgments cannot violate principles of public policy (orden público) of Argentine law, as determined by Argentine courts. It is possible that an Argentine court would deem the enforcement of foreign judgments ordering us to make a payment in a foreign currency outside of Argentina to be contrary to Argentine public policy if at that time there are legal restrictions prohibiting Argentine debtors from transferring foreign currency outside of Argentina. Although currently there are no legal restrictions prohibiting Argentine debtors from transferring foreign currency outside of Argentina to satisfy principal or interest payments on outstanding debt that has been previously reported to the BCRA, we cannot assure you that the Government or an Argentine court will not impose such restrictions in the future.

In addition, under Argentine law, attachment prior to execution and attachment in aid of execution will not be ordered by an Argentine court with respect to property located in Argentina and determined by such courts to be utilized for the provision of essential public services. A significant portion of our assets may be considered by Argentine courts to be dedicated to the provision of an essential public service. If an Argentine court were to make such a determination with respect to any of our assets, unless the Government ordered the release of such assets, such assets would not be subject to attachment, execution or other legal process if such determination stands, and the ability of any of our creditors to realize a judgment against such assets may be adversely affected.

The Government’s strategies, measures and programs with respect to the natural gas transportation industry could materially adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

Since 1992 and after the privatization of several state companies, until the economic crisis in 2002, the Government reduced its control over the natural gas transportation industry. After the economic crisis in 2002 the Government increased its role in the energy sector implementing strict regulations and increasing its intervention. Intervention primarily included the expansion of our pipeline through the creation of trust funds and the interruption and redirection of natural gas firm transportation services (including the diversification of natural gas supply from our liquids processing plant located at General Cerri Complex, in the Province of Buenos Aires (“Cerri Complex”).

In the past, natural gas distribution companies, including us, were prohibited from passing through price increases to consumers. Producers of natural gas, therefore, had difficulty implementing wellhead natural gas price adjustments that would increase the costs of distribution companies, which caused such producers to suffer a sharp decline in their rate of return-on-investment activities. As a result, natural gas production was not sufficient to meet the increasing demand. Likewise, the lack or insufficient tariff adjustments for natural gas transportation companies caused a decrease in the profitability of such companies.

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Considering these events, the Government implemented a number of strategies, measures and programs aimed at mitigating the energy crisis and supporting the recovery of the Argentine economy generally. These strategies, measures and programs included, among others, the expansion of our pipeline through the creation of financial trust funds used as vehicles to facilitate financing of those investments (“Gas Trusts”). Although the expansion projects described above have not adversely affected our results of operations or financial condition, we cannot assure you that future, or even present, expansion projects will not have such adverse effects.

On December 20, 2019, the Argentine congress enacted Law No. 27541 (the “Solidarity Law”). The Solidarity Law establishes the restructuring of the energy tariff scheme and froze the natural gas and electricity tariffs. In addition, the Solidarity Law entitles the Argentine Executive Branch to intervene the ENARGAS. On March 17, 2020, Decree No. 278/2020 was published in the Official Gazette, which provides for the State intervention in ENARGAS until December 31, 2020. Afterwards, the intervention was extended until December 31, 2023, by means of Decree No. 815/2022.

Within the framework of the measures adopted as a result of the restrictions imposed to face the sanitary emergency arising from the COVID pandemic, the Government took a series of measures to mitigate its impact on certain socioeconomic sectors. Within this framework, during 2020, service cuts to non-paying residential users were suspended, the “Gas.Ar Plan” was created with the purpose of promoting natural gas production and certain limitations to tariff increases were imposed to keep pace with the evolution of inflation and cost increases.

We cannot predict what other measures or strategies will be adopted by the Government to mitigate in the natural gas industry, nor the effect that such measures may have on our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

A significant portion of our revenues is generated under natural gas transportation contracts that must be renegotiated and/or extended periodically.

In 2022, 83% of our average daily natural gas deliveries were made under long-term firm transportation contracts. As of December 31, 2022, our long-term firm natural gas transportation contracts had a remaining weighted average life of approximately 11 years; our long-term firm natural gas transportation contracts with our top five costumers had a remaining weighted average life of approximately eight years. We cannot assure you that we will be able to extend or replace these contracts when they expire or that the terms of any renegotiated contracts will be as favorable as the existing contracts. In particular, our ability to extend and/or replace contracts could be adversely affected by factors we cannot control, including:

• Argentine natural gas transportation regulations;

• international oil and gas prices;

• timing, volume and location of new market demand;

• competition from alternative energy sources;

• supply and price of natural gas in Argentina;

• demand for natural gas in the markets we serve; and

• availability and competitiveness of alternative gas transportation infrastructure in the markets we serve.

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Additionally, most of our transportation contracts include a clause allowing for the termination of the relevant contract before the expiration of its term by any of the parties, in case of (i) breach of the other party, or (ii) an extended event of force majeure.

Our business may require substantial capital expenditures for ongoing maintenance requirements and the expansion of our installed transportation capacity; we could be unable to make such expenditures due to the lack of financing.

Resolution 4362 stated that we should have executed he Five-Year Plan. Because of the beginning of the new RTI process the Five-Year Plan was suspended. Additionally, as part of the measures adopted to reduce the impact of COVID and in order to adapt our business plan to the economic expectations of Argentina, we have implemented a reduction in the current investment plans, without compromising safety, which allows us to guarantee continuity in the development of our activities.

The natural gas transportation service is an activity involving significant amounts of capital expenditures in order to improve the operation and maintenance of the pipeline system. Incremental capital expenditures may be required to fund maintenance of our pipeline system. Furthermore, capital expenditures will be required to finance current and future expansions of our transportation capacity. If we are unable to finance any such capital expenditures in terms satisfactory to us or at all, our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations may be adversely affected. In addition, our financing ability may be limited by market restrictions on financing availability for Argentine companies. See “—Risks Relating to Argentina—Argentina’s past default and litigation with holdout bondholders may limit our ability to access international markets.”

In the past, expansion projects by the Government have not had adverse effects over our results of operations and financial condition. However, we cannot assure you that future expansion projects will not adversely affect our business.

Our Liquids production depends on the natural gas that arrives at the Cerri Complex through three main pipelines from the Neuquina, Austral and San Jorge natural gas basins. The flow and heating value of this natural gas are subject to risks that could materially adversely affect our Liquids and midstream business segment.

More than 50% of the energy matrix in Argentina relies on natural gas. However, its natural gas reserves are declining. Despite the decline in 2015 and 2016, the volume of natural gas that has been produced from the Neuquina basin has increased. More recently, natural gas production in Argentina has increased thanks to the development of Vaca Muerta, despite the decline of the basins where conventional gas predominates. Although production volume increased in recent years, it had previously decreased between 2009 and 2013 and it is possible that natural gas production will again decrease in the future, which would adversely affect our Liquids business segment by reducing the amount of natural gas flowing to the Cerri Complex and, therefore, the amount of Liquids we produce. In addition, the reduction in the production of natural gas could affect the flow of natural gas provided for our midstream services.

Since 2009, the quality and volume of natural gas injected from the Neuquina basin has been lower (because of the reduction of natural gas production in this basin) and not appropriate for processing in the Cerri Complex, negatively impacting our level of output from this facility. Because of this lower output of natural gas from the Neuquina basin, we have had to buy natural gas at higher prices, causing an increase in the cost of Liquids production and commercialization activities for our own account reducing our profit from these activities. In addition, competition might affect the volume and quality (i.e., gas with lower liquids content) of natural gas arriving at the Cerri Complex.

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In 2009, nonconventional natural gas was discovered in the Vaca Muerta field of the Neuquina basin by YPF. Exploration and exploitation of this natural gas reserve involved high extraction costs. Argentina’s national natural gas production has steadily increased in the past three years, largely due to the increased production of shale from the Vaca Muerta formation. Because of the measures taken by the Government production levels throughout the Neuquina basin has increased in recent years, except during 2020 which was affected by COVID pandemic and the effects of the preventive and mandatory lockdown measures, combined with a higher autumn temperature.

The Neuquén basin, with 68% of the national production, where most of the unconventional of non-conventional developments, explains the year-on-year increase. The rest of the basins decrease their production in the twelve-month accumulated measurements (except for the Cuyana basin, which has a low representation in the national the Cuyana basin of low representativeness).

However, after the freezing of fuel prices and the current economic situation that Argentina is experiencing, there is uncertainty regarding the investments that natural gas producers can make in that area. The Gas.Ar Plan establishes the need to guarantee the supply of natural gas demand while establishing incentives to make immediate investments for the maintenance and/or growth of production in the productive basins, where the natural gas producers must commit themselves to achieve a production curve that guarantees the maintenance and/or increase of the current levels.

We cannot assure you, however, that this new natural gas resource at the Neuquina basin, or the Gas.Ar Plan, or any other measures taken by the Government to increase natural gas production and supply (including pipeline expansion projects and the construction of new pipelines such as the Tratayén-Salliqueló-San Jerónimo pipeline), will be successful in increasing Argentine natural gas reserves or production and, if unsuccessful, our midstream or Liquids Production and Commercialization businesses could be adversely affected.

Measures taken by the Government may have an adverse effect on the supply of natural gas to the Cerri Complex and the margins we are able to obtain from our Liquids business, which may adversely affect the results in our Liquids Production and Commercialization segment and, as a result, our overall business and results of operations.

Due to regulatory, economic and government policy factors, domestic gasoline, diesel, natural gas, propane and butane, and other fuel prices and related services have differed substantially from prevailing international and regional market prices for such products and services. Our ability to increase prices in connection with international price or domestic cost increases, including those resulting from the peso devaluation, has been limited from time to time. The prices that we are able to obtain for our products and services affect the viability of investments in expansion capacity and processing facilities and, as a result, the timing and amount of our capital expenditures for such purposes.

Although our Liquids production and commercialization activities are not subject to regulation by ENARGAS, with the aim to give priority to domestic supply, the Government has taken certain regulatory actions in recent years that have affected our Liquids business. For example, in April 2005, the Government enacted Law No. 26,020, which set the framework by which the SHR may establish regulations to cause LPG suppliers to guarantee sufficient supply of LPG in the domestic market at low prices. Law No. 26,020 creates a price regime pursuant to which the SHR periodically publishes reference prices for LPG sold in the local market. It also sets forth LPG volumes to be sold in the local market.

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We participate in two programs created by the Government under this framework, which provide for the payment of compensation based on the difference between the price set by the Government and the export parity price. Over recent years, this compensation has been paid to us with significant delays. For further information, see “Item 4—Our Information—B. Business Overview—Liquids Production and Commercialization.”

On March 25, 2020, after COVID pandemic, the Executive Branch issued Decree No. 311/2020, which determines that the maximum reference price for LPG sold in the domestic market will remain at their values in force at such date for a 180-day period.

Beginning 2021, prices of the products sold under these programs slightly increased. In August 2021, within the framework of Plan Hogar, the Secretary of Energy through Res. No. 809/2021 provided financial assistance to butane producers. The assistance was effective from August 2021 to December 2022 inclusive.

Also, we cannot assure you that we will be able to maintain or increase the domestic prices of our products, and limitations on our ability to do so would adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations. Similarly, we cannot assure you that LPG prices in Argentina will track increases or decreases in the international or regional markets.

Our Liquids business is highly dependent on the supply of natural gas to the Cerri Complex at reasonable prices that allow for reasonable profit margins.

Since 2017, the Government has taken a series of necessary measures to initiate a convergence between the local price of natural gas and the international price. However, during 2018, due to a combination of internal and external factors, the increase in natural gas and fuel prices was significant which meant that the intended liberalization was unsuccessful.

During 2018, the Government introduced several changes to the process by which the natural gas is acquired for the electric energy generators. Among them, modifications were introduced to the regulations through which Compañía Administradora del Mercado Mayorista Eléctrico S.A. (“CAMMESA”), a government-controlled company, had to provide this supply to the power plants. Finally, on November 6, 2018, the Secretary of Energy issued Resolution No. 70/2018, which returned to power generators the ability to purchase their own natural gas supply. Most of the power generators recovered the ability to do so, therefore, the price of natural gas purchased under the bidding processes decreased further because of the competition for demand in the low consumption season and in an environment with oversupply and economic recession.

However, Secretary of Energy Resolution No. 12/2019 abrogated SGE Resolution No. 70/2018 and returned to CAMMESA centralized fuel supply scheme as established in Secretary of Energy Resolution No. 95/2013, as amended.

The prices at which power plants or CAMMESA acquire natural gas can be considered a reference to determine the price of natural gas acquired by us as shrinkage gas (“RTP”), which is why any additional increase in the costs of our Liquids Production and Commercialization segment may adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

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As described above, actions taken by the Government during winter periods of recent years resulted in natural gas being redirected away from certain users, including the Cerri Complex, toward priority users, including residential customers. See above “—The Government’s strategies, measures and programs with respect to the natural gas transportation industry could materially adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.” To a lesser extent, during the winter of 2016 and 2017, processing at the Cerri Complex was interrupted because of continued governmental actions to ensure natural gas supply to the domestic market, but thanks to the development of the Vaca Muerta formation, during the five-year period ended December 31, 2022, we did not register any interruption in the supply of natural gas in the Cerri Complex.

Additionally, in view of the scarcity of natural gas supply, the national government has resorted to importing liquefied natural gas (“LGN”) (which is regasified in the ports located in the cities of Escobar and Bahía Blanca, in the province of Buenos Aires) and natural gas from Bolivia. The recent war between Ukraine and Russia resulted in a significant increase in natural gas prices. In view of the country’s fiscal situation, it is not possible to guarantee that Argentina will be able to acquire all the natural gas and LGNs necessary to meet demand. Likewise, this situation caused difficulties in the negotiations between Argentina and Bolivia to extend the agreement to import natural gas from Bolivia. More recently, Argentina and Bolivia agreed the extension of the agreement but reducing the quantity of natural gas offered by Bolivia.

In the event that Argentina is unable to meet the demand, it is highly likely that there will be scheduled natural gas outages during the winter to certain non-priority users (among them the Cerri Complex).

In addition, regarding natural gas producers, the Government has recently introduced measures to moderate the impact of fuel prices in the economy. The prices that natural gas producers are able to obtain for oil and natural gas affect the viability of investments in new exploration, development and refining and, as a result, the timing and amount of our projected capital expenditures for such purposes. Any diversion of the supply of natural gas from the Cerri Complex may require us to purchase natural gas from third parties to supply our Liquids business, which may result in increased costs. If we are unable to purchase natural gas from other sources, the volume of our Liquids productions may decrease.

After the first award of volumes and prices carried out on December 3, 2020, under the framework of Gas.Ar Plan, an increase in the natural gas price at the Point of Entry to the Transportation System (the “PIST” after its acronym in Spanish) for thermal generation and for natural gas distributors was verified, which is highly likely to affect industrial users, which will ultimately impact the costs of natural gas consumed in the Cerri Complex, thus affecting our operating margins. However, such plan would allow the drop in production levels that has been recorded in recent periods to be reversed in order to sustain our gas processing business at the Cerri Complex.

It is uncertain whether in the future measures taken by the Government or other measures that could adversely affect our business, results of operations and ability to meet our financial obligations will be implemented. It is also uncertain the impact of the Solidarity Law, regulations to be issued under its framework or whether our regulatory obligations may be increased, which could result in higher taxes, amendments to the tariff structure, or any other obligations that could increase our costs and adversely affect our financial situation.

Fluctuations in market prices and the enactment of new taxes or regulations limiting the sales price of LPG and natural gasoline may affect our Liquids business.

We extract LPG and natural gasoline from natural gas delivered to the Cerri Complex and sell LPG and natural gasoline. As a result of the deterioration of our Natural Gas Transportation segment, operations relating to our Liquids production and commercialization have represented more than 50% of our total revenues between 2004 and 2017 and during fiscal years 2021 and 2022.

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Over the last few years, the price of Liquids has experienced high levels of volatility. Factors affecting prices include weak demand levels from emerging markets, significant variations in production and storage levels, and climate and geopolitical issues such as the Russia-Ukraine and Middle East conflicts, the ability of the OPEC and other crude oil producing nations to set and maintain crude oil production levels and prices; macroeconomic conditions, including inflation and increase in interest rates. It is expected that volatility and fluctuations maintained in the future.

We cannot predict how these factors will influence LPG and natural gasoline prices and we have no control over them. Price volatility curtails the ability of industry participants to adopt long-term investment decisions given that returns on investments become unpredictable. A substantial or extended downturn in the international prices of Liquids could have a material adverse effect on our business, operating results, and financial condition, as well as the market value of our shares or ADSs.

In the past, the Argentine government has imposed duties on exports, including exports of natural gasoline and LPG products that we export. Currently, in accordance with the Solidarity Law and Decree 488/2020 export duties on the Liquids products that we exported are 8%. For further information, see “Item 4. Our Information—B. Business Overview—Liquids Production and Commercialization.”

In addition, after the issuance of Resolutions Nos. 1,982/11 and 1,991/11 (the “Gas Charge Resolutions”), the natural gas processing charge created by Decree No. 2,067/08 (the “Natural Gas Processing Charge”) increased from Ps.0.049 to Ps.0.405 per cubic meter of natural gas effective from December 1, 2011, representing a significant increase in our variable costs of natural gas processing.

In order to avoid an adverse effect on our Liquids business, we initiated legal proceedings against Decree No. 2,067/08 and the Gas Charge Resolutions, including the Government, ENARGAS and the former Ministerio de Producción y de Planificación Federal, Inversión Pública y Servicios (the “MPFIPyS”) as defendants.

On March 28, 2016, the former Ministry of Energy issued Resolution No. 28 (“Resolution 28”), which instructs ENARGAS to take all the necessary measures to reduce to zero the Natural Gas Processing Charge starting April 1, 2016. Since that date, we have not been required to pay for the Natural Gas Processing Charge. However, Resolution 28 did not invalidate the Natural Gas Processing Charge or Gas Charge Resolutions for the period in which they were in force, for which reason the judicial action is still ongoing. On March 26, 2019, we were served notice of the first instance judgment rendered in the proceedings, which upholds the legal action filed by us and declares the unconstitutionality of Executive Decree No. 2,067/08, MPFIPyS Resolution No. 1451/08 and the Gas Charge Resolutions, and Section 53 and 54 of Act No. 26,784 (General budget of the National Public Administration for the fiscal year 2013), as well as of any other act aimed at enforcing Executive Decree No. 2,067/08, and therefore declares invalid said regulations. On March 29, 2019, the Secretary of Energy appealed the judgment, which appeal was granted on April 3, 2019. On December 1, 2020, the judge resolved to extend the injunction (medida cautelar) for six months, or until the award becomes final. On May 14, 2021, we were notified that such judgment (i) was revoked, and (ii) costs were imposed for both instances in the order caused. For additional information, see “Item 8. Financial Information—A. Consolidated Statements and Other Financial Information—Legal and Regulatory Proceedings—Tax Claims.”

Any new regulations regarding the cost and availability of the natural gas used in the production of Liquids and the effect of the continuing decline or volatility in international prices of LPG or natural gasoline could cause our operating margins to drop significantly and materially adversely affect our business, results of operations, financial condition, the value of our securities, and our ability to meet our financial obligations. In addition, the Government could modify the current taxes and export/import regulations in a manner that could adversely affect our financial condition and results of operations.

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Our business, financial condition and results of operations have been, and may continue to be, adversely affected by the ongoing COVID pandemic and the emergence of a pandemic-level disease or threat to public health.

Outbreaks of contagious diseases and other adverse public health developments affecting us and/or the third parties on which we rely, could have a material and adverse effect on our business, financial condition and results of operations.

The COVID pandemic has introduced uncertainty in a number of areas of our business, including our operational, commercial and financial activities. The COVID pandemic has impacted, and is continuing to impact, many aspects of society, including the operation of healthcare systems, global travel, supply and labor markets and other business and economic activity worldwide. Argentina and countries around the world have, at times during the pandemic, issued and implemented quarantines, vaccine and masking mandates, executive orders and other similar government orders, restrictions and recommendations for their residents to help control the spread of COVID. Such orders, mandates, restrictions and/or recommendations have, at times during the pandemic, resulted in widespread interruptions and closures of businesses, including healthcare systems that serve people living with addiction and serious mental illness, work stoppages, slowdowns and/or delays, remote work policies and travel restrictions, among other effects.

COVID has also impacted negatively, and may continue to impact negatively, global economic activity, demand for energy including NGL and funds flows and sentiment in the global financial markets.

The outbreak of the coronavirus has caused significant social and market disruption. Any prolonged restrictive measures put in place in order to control an outbreak of a contagious disease or other adverse public health development such as the ongoing COVID outbreak, may have a material and adverse effect on our business operations, financial condition or operational results. Our activity has been declared essential during the COVID pandemic; therefore, we adopted all necessary measures to ensure the continuity of our operations such as reverting isolated cells for essential operation workers during the peaks of the COVID and carried out frequent antigen tests for rapid detection of positive cases, among other measures.

The long-term effects to the global economy and the Company of the COVID pandemic are difficult to assess or predict and may include a further decline in the market prices of our Shares and ADSs, risks to employee health and safety, risks for the deployment and logistic of our services and reduced sales mainly in the Liquids business segment. Our share price has recently declined significantly, due in part to the impact of the COVID.

The COVID pandemic has caused, and may continue to cause, varying degrees of disruption to our employees, our communities and our business operations. While we have continued to operate our facilities and to performed essential works in our facilities without interruption throughout the pandemic, any prolonged labor or supply chain shortages at our facilities could impact our ability to receive revenue in a timely matter.

The COVID pandemic has also impacted, and may continue to impact, the regulatory agencies with which we interact.  For example, travel restrictions, social distancing, quarantine protocols and other protective measures may impact the timelines and way the ENARGAS, the Secretary of Energy and other regulatory agencies conduct regulatory activities, which may, in turn, negatively impact expected timelines for regulatory measures and approvals, which could have an adverse effect on our business and the market price for our ordinary shares.

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We cannot assure the duration and consequences of COVID or any other disruptions that may arise in government intervention or other measures, or the possibility of other economic effects on the stock market, foreign exchange rates and otherwise. Any such negative impact could result in a material adverse effect on our business, liquidity, financial conditions, results of operations and trading price of our common shares and ADSs.

Our ethane sales depend on the capacity of PBB, as the sole purchaser of our ethane production.

Between 2005 and 2015, we sold all our ethane to PBB under a long-term agreement that expired on December 31, 2015, which was subsequently renewed on an annual basis until May 1, 2018, and then on a monthly basis until September 6, 2018, the date on which we entered into a new agreement with PBB. The agreement is retroactive as of May 1, 2018 and will expire on December 27, 2027.

Pursuant to this agreement, the ethane price is calculated in U.S. dollars and is subject to adjustments, the natural gas price, the quality of the ethane shipped by us and transportation tariffs and charges, among others. This agreement also includes take or pay (“TOP”) and deliver or pay (“DOP”) commitments for minimum annual quantities. Under these terms, if one party does not comply with the applicable TOP or DOP condition, that party will be required to compensate the other party.

In the past, PBB suffered several adverse operational conditions that affected its capacity to purchase our ethane production. We cannot assure you that these adverse conditions affecting PBB will not recur in the future or that PBB will be able to satisfy its obligations under the new purchase agreement. Likewise, if we are not able to renegotiate such agreement at maturity on terms similar to those in effect, our financial condition and results of operations could be adversely affected.

The affirmative and restrictive covenants in outstanding indebtedness could adversely restrict our financial and operating flexibility and subject us to other risks.

The terms of our outstanding indebtedness provide for numerous affirmative and restrictive covenants that limit our ability to, among other things:

• incur or permit to exist certain liens;

• incur additional indebtedness;

• pay dividends or make other restricted payments;

• make capital investments and other investments;

• enter into sale and lease-back transactions;

• enter into transactions with affiliates;

• sell, transfer or otherwise dispose of assets; and

• consolidate, amalgamate, merge or sell all or substantially all of our assets.

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These restrictions may limit our ability to operate our businesses and may prohibit or limit our ability to enhance our operations or take advantage of potential business opportunities as they arise. The breach of any of these covenants by us or the failure by us to meet any of these conditions could result in a default under any or all of such indebtedness. Our ability to comply with these covenants may be affected by events beyond our control, including prevailing economic, financial and industry conditions and the renegotiation of the public works and licenses process. In addition, if we are unable to generate sufficient cash flow from operations, we may be required to refinance outstanding debt or to obtain additional financing. We cannot assure you that a refinancing would be possible or that any additional financing would be available or obtained on acceptable terms.

Our insurance policies may not fully cover damage or we may not be able to obtain insurance against certain risks.

We maintain insurance policies intended to mitigate our losses due to customary risks. These policies cover our assets against loss for physical damage and loss of revenue, and also third-party liability. However, we cannot assure you that the scope of damages suffered in the event of a natural disaster or catastrophic event would not exceed the policy limits of our insurance coverage. We maintain all-risk physical damage coverage for losses resulting from, but not limited to, earthquakes, fire, explosions, floods, windstorms, strikes, riots, mechanical breakdowns and business interruption. Our level of insurance may not be sufficient to fully cover all losses that may arise in the course of our business or insurance covering our various risks may not continue to be available in the future. In addition, we may not be able to obtain insurance on comparable terms in the future. We may be materially and adversely affected if we incur losses that are not fully covered by our insurance policies or if we are required to disburse significant amounts from our own funds to cover such losses.

Changes in the interpretation by the courts of labor laws that tend to favor employees could adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

In addition to our employees, we rely on several third-party service providers to outsource certain services. We follow very strict policies to control the compliance by such third-party service providers with their labor and social security obligations. However, due to changes in the interpretation by the courts of labor laws that tend to favor employees in Argentina, companies’ labor and social security obligations toward their own employees and employees of third-party service providers have significantly increased. As a result of the foregoing, potential severance payment liabilities have significantly increased, and in the event any third-party service provider fails to duly comply with its labor and social security obligations towards its employees, we may be faced with litigation by employees of such third-party service provider to hold us liable for the payment of any labor and social security obligations defaulted on by any such third-party service provider. Therefore, our labor costs may increase as our indemnification responsibilities and costs expand, adversely affecting the results of our operations.

We may be exposed to risks related to litigation and administrative proceedings that could materially and adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations in the event of an unfavorable ruling.

We are part of administrative proceedings and judicial claims, some of which have been pending resolution for several years. Our business may expose us to litigation relating to labor, environmental, health and safety matters, regulatory, tax and administrative proceedings, governmental investigations, tort claims and contract disputes and criminal prosecution, among other matters. In the context of these proceedings, we may be required to pay fines or money damages and we also may be subject to complementary sanctions or injunctions affecting our ability to continue our operations. While we may contest these matters vigorously and make insurance claims when appropriate, litigation and other proceedings are inherently costly and unpredictable, making it difficult to estimate accurately the outcome of actual or potential litigation or proceedings. Although we may establish provisions, as we deem necessary, the amounts that we reserve could vary significantly from any amounts we pay due to the inherent uncertainties in the estimation process.

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For additional information on the material proceedings in which we are involved, see “Item 8. Financial Information—A. Consolidated Statements and Other Financial Information—Legal and Regulatory Proceedings.”

Our operations are subject to environmental, occupational health and safety regulations.

We operate an extensive network of natural gas pipelines, including numerous compressor plants, the Cerri Complex and the logistic and storage facilities of Puerto Galván. All these facilities are located throughout the territory of Argentina and are subject to federal and provincial laws, as well as to the supervision of governmental agencies and regulatory authorities in charge of enforcing environmental laws and policies. We operate in compliance with applicable laws and in accordance with directives issued by ENARGAS. For this reason, it is possible that we could be subject to controls, which could result in penalties imposed on us.

We utilize a certified safety, occupational health, environment and quality management system in accordance with international standards ISO 14001, ISO 9001 and OHSAS 18001. It includes operational controls that are documented and monitored regularly. However, we cannot assure you that these controls will be effective or that our time of response to incidents will be adequate.

In addition, future regulation may require us to comply with additional safety, occupational health, environmental and quality controls or standards. We cannot assure you that, in the future, additional regulation could be issued requiring us to make new investments in order to comply with such safety, health and environmental laws and regulations.

Our operations could cause environmental risks and any change in environmental laws could increase our operating costs.

Some of our operations are subject to environmental risks that could arise unexpectedly and cause material adverse effects on our operational results and financial condition. In addition, the occurrence of any of these risks could lead to personal injury, loss of life, environmental damage, repair and expenses, equipment damage and liability in civil, criminal and administrative proceedings. We cannot assure you that we will not incur additional costs related to environmental issues in the future, which could adversely affect our operational results and financial condition. In addition, we cannot ensure that our insurance coverage is sufficient to cover the losses that could potentially arise from these environmental risks.

Moreover, we are subject to a broad range of environmental legislation, both in Argentina and in other countries where companies we have interests in are located.

Local, provincial and national authorities in Argentina and other countries where companies we have interests in are located may implement new environmental laws and regulations and may require us to incur higher costs to comply with new standards. The imposition of more stringent regulatory and permit requirements in relation to our operations in Argentina could significantly increase the costs of our activity. We cannot predict the effects of the implementation of any new environmental laws and regulations on our financial condition and operational results.

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We may face competition.

Historically, the construction and operation of natural gas processing plants located in the Province of Neuquén has increased competition in our Liquids sector as our customers could satisfy their product demand with alternative suppliers. In the past, we have been able to mitigate this competition by entering into agreements with natural gas producers that limited their ability to make investments in natural gas processing plants.

Although the construction of gas processing plants upstream of the Cerri Complex requires significant investments, additional gas processing facilities may be constructed could result in lower volumes or inferior natural gas quality of the natural gas arriving at the Cerri Complex in the future. Therefore, there is a risk that additional gas processing at the MEGA plant could result in lower volumes or lesser quality gas arriving at the Cerri Complex in the future, or that other projects that may be developed upstream of the Cerri Complex could adversely affect our revenues from Liquids production and commercialization services. In order to guarantee access to natural gas to be processed in the Cerri Complex we have obtained the commitment of natural gas producers to not build natural gas processing plants upstream of the Cerri Complex during the term of such long-term agreements.

Regarding our Other Services business segment, we operate in a market with strong participants, many of which may have extensive and diversified know-how or operating experience and financial resources like or significantly greater than ours. While it is still unclear the future measures to be taken by the Government regarding its energetic policy, the development of the natural gas industry in Argentina is essential for the country’s economic growth. All future business that our competitors or we can develop will depend on the production of natural gas. The Government (or any other entity on its behalf) might not issue the necessary regulations to encourage natural gas producers to develop new projects involving natural gas output.

Our competitors may be able to invest more for productive natural gas properties than our financial or personnel resources permit. Our competitors may also be able to offer better compensation packages to attract and retain qualified personnel than we are able to offer.

As a result of the above, an increased number of competitors could reduce the quality of the natural gas available for its processing, our ability to attract and retain quality personnel or raising additional capital. In addition, an increase in competition could affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations. This would adversely affect our business, results of operations and financial condition.

Additionally, our principal competitor in the gas transportation business is Transportadora de Gas del Norte S.A. (“TGN”). We compete with TGN on a day-to-day basis for natural gas interruptible transportation services and from time to time for new natural gas firm transportation services made available as a result of expansion projects to the natural gas distribution companies to which both we and TGN are either directly or indirectly connected (Camuzzi Gas Pampeana S.A., Metrogas S.A. and Naturgy Argentina S.A.). We compete directly with TGN for the transportation of natural gas from the Neuquina basin to the greater Buenos Aires area. In addition, in the future other participants may successfully penetrate our market and connect with our main customers which could affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

  Currently the development of Vaca Muerta depends on the availability of transport infrastructure. In particular, most of natural gas production from the Neuquina basin is transported through Neuba I and Central Oeste pipelines these pipelines are currently working close to full capacity. If Vaca Muerta production grows at a greater pace than its capacity expands, a potential lack of transportation capacity may limit our the development of new businesses and increase competition affecting our financial condition and results of operations.

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On February 7, 2022, the Secretary of Energy issued Resolution No. 67/2022 whereby the Natural Gas Pipeline System Program was created and the construction of the President Néstor Kirchner Natural Gas Pipeline (the “NK Pipeline”) was declared of public interest. Also, by means of Decree No. 76/2022 of February 11, 2022, the concession of such natural gas pipeline was granted to IEASA for a term of 35 years.

In a first stage, the construction of the NK Pipeline will connect the town of Tratayén in the Province of Neuquén with the town of Salliqueló in the Province of Buenos Aires, where it will be connected to the natural gas pipeline system operated by us. The second stage will consist of the construction of the gas pipeline section to San Jerónimo in the south of the Province of Santa Fé. The first stage of this pipeline will length 356 miles, while the total length it is plan in 648 miles.

The construction of a new pipeline by a third party could affect our results of operations as the interruptible natural gas transport volumes and the availability of natural gas that arrives at the Cerri Complex for processing could be diminished.

Downgrades in our credit ratings could have negative effects on our funding costs and business operations.

  Credit ratings are assigned to the Company and its subsidiaries. The credit ratings are based on information furnished by us or obtained by the credit rating agencies from independent sources and are also influenced by the credit ratings of Argentine Government bonds and general views regarding the Argentine financial system as a whole. The credit ratings are subject to revision, suspension or withdrawal by the credit rating agencies at any time. A downgrade, suspension or withdrawal in our credit ratings could result in, among others, the following: (i) increased funding costs and other difficulties in raising funds; (ii) the need to provide additional collateral in connection with financial market transactions; and (iii) the termination or cancellation of existing agreements. As a result, our business, financial condition and operational results could be materially and adversely affected.

Our business has become dependent on digital technologies to conduct day-to-day operations and we may be subject to cyberattacks or other risks related to new technologies.

We depend on a variety of internet-based data processing, communication, and information exchange platforms and networks. Although we have extended our security policy to cover industrial systems, reinforcing our defenses in case of denial of service and increasing the monitoring of suspicious activities, our technologies, systems and networks and those of our business associates may be exposed to cyberattacks and other cybersecurity incidents in the normal course of business, which could lead to disruptions in critical systems (such as our electronic flow measurement system and distributed control systems), the unauthorized release of confidential or protected information, corruption of data or other disruptions of our business operations.

Information security risks have generally increased in recent years as a result of the proliferation of new technologies and the increased sophistication and activities of cyber-attacks. More recently we extended remote work environments which may be less secure and more susceptible to hacking attacks, including phishing and social engineering attempts.

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Our information technology infrastructure is critical to the efficient operation of our business and is essential to our ability to perform day-to-day operations. Breaches in our information technology infrastructure or physical facilities, or unauthorized access or other loss of information or other disruptions, could result in damage to our assets, safety incidents, legal claims, potential liability or the loss of contracts, damage our reputation, and could have a material adverse effect on our operations, financial position and results of operations.

Our natural gas transportation systems and processing facilities are subject to the risk of mechanical or electrical failures and any resulting unavailability may affect our ability to fulfill our contractual and other commitments and thus adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

Our natural gas transportation systems and processing facilities are at risk of mechanical or electrical failures and may experience periods of unavailability affecting our ability to comply with our contracts with customers. Any unplanned unavailability of our natural gas transportation systems and processing facilities may adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations, as we may be subject to fines or penalties under our contracts with customers.

Our business is subject to risks arising from natural disasters, catastrophic accidents and terrorist attacks.

Our facilities or the third-party infrastructure that we rely on may be damaged by flooding, fires and other catastrophic disasters arising from natural or accidental or intentional human causes. We could experience severe business disruptions, significant decreases in revenues based on lower demand as a result of catastrophic events, or significant additional costs to us not otherwise covered by business interruption insurance clauses. There may be a significant time lag between a major accident, catastrophic event or terrorist attack and our definitive recovery from our insurance policies, which typically carry nonrecoverable deductible amounts, and in any event are subject to caps per event. In addition, any of these events could adversely affect the demand of natural gas by some of our customers and of consumers generally in the affected market. Some of these considerations, among others, could materially and adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

We are subject to anti-trust, sanctions, anti-bribery and anti-money laundering laws. Failure to comply with these laws could result in penalties, which could harm our reputation and have an adverse effect on our business.

We are subject to anti-trust, sanctions, anti-bribery and anti-money laundering laws. Although we maintain policies and processes intended to comply with these laws, including a review of our internal control over financial reporting, we cannot ensure that these compliance policies and processes will prevent intentional, reckless or negligent acts committed by our officers or employees. If our officers or employees fail to comply with any applicable anti-trust, anti-corruption, anti-bribery or anti-money laundering laws, they may be subject to criminal, administrative or civil penalties and other remedial measures, which could have material adverse effects on our business, financial condition, results of operations and prospects.

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On March 1st, 2018, Law No. 27401 entered into force (the “Law 27401”). This Law modifies the Argentine Criminal Code (“ACC”) and imposes criminal liability to private legal persons, whose corporate capital is either national or foreign, with or without state ownership. The Law 27401 imposes criminal liability to legal persons for the following crimes: (i) Local or international bribery and influence peddling (section 258 and 258bis of the ACC); (ii) Negotiations incompatible with public office (section 265 of the ACC); (iii) Extortion by public officers (section 268 of the ACC); (iv) Unjust enrichment by public officers and employees (section 268 (1) and (2) of the ACC); (v) Falsification of balance sheets and reports (section 300 bis of the ACC). Legal persons are liable for the abovementioned crimes when, either direct or indirectly, the entity intervened in the commission of the crime or when someone acted in his name, interest or benefit for said purpose; even when this individual had no powers to do so, provided that the legal person ratified the act. The legal person will not be criminally liable when the entity reported a crime set forth by the Law 27401 as a consequence of the entity´s internal detection and investigation; the corporate implementation of a proper system of control and supervision in accordance with the Law 27401 and prior to the facts under investigation; and after returning the benefit obtained. In relation to this, the Law 27401 highlights the importance of “Integrity Programs” or “Internal Rules of Compliance” adopted by the legal person before the commission of the crime, and hence it is important to implement this type of rules into the legal person.

In the framework of Law 27401 on Criminal Responsibility of Legal Entities, we have implemented an Integrity Program. It should be noted that prior to the enactment of Law 27401, we already had a Code of Conduct and a Whistleblowing Hotline. It is also important to note that, as we are a publicly traded company, we are subject to the provisions issued by the CNV, as well as the provisions of the General Companies Law and other regulations issued by the competent authorities in the matter. (see “Item 16B. Code of Ethics”).

In addition, we are subject to economic sanctions regulations that restrict our dealings with certain sanctioned countries, individuals and entities. In the ordinary course of business, we deal with different suppliers, contractors, vendors and counterparties that may become subject to sanctions. It is possible that existing sanctions regimes may be widened or that new sanctions may be imposed on our counterparties, by the United States, the European Union, the United Kingdom or other jurisdictions. Although we take steps to comply with applicable laws and regulations, should these suppliers, contractors or vendors become sanctioned or the sanctions regime with respect to these entities be widened and we no longer can rely on such suppliers, contractors or vendors, or should we fail to successfully comply with applicable sanctions, we may face negative legal and business consequences.

There can be no assurance that our internal policies and procedures will be sufficient to prevent or detect all inappropriate practices, fraud or violations of law by our affiliates, employees, directors, officers, partners, agents and service providers or that any such persons will not take actions in violation of our policies and procedures. Any violations by us of anti-bribery and anti-corruption laws or sanctions regulations could have a material adverse effect on our reputation, business, financial condition, results of operations and prospects.

Our ability to operate our business may suffer if we are unable to retain our employees or attract other skilled employees or contractors.

Our current and future performance and the operation of our business are dependent upon the contributions of our senior management and our skilled team of engineers and other employees. We depend on our ability to attract, train, motivate and retain key management and specialized personnel with the necessary skills and experience.

Further, COVID poses a threat to the well-being and morale of our employees. In response to the COVID pandemic, we formally established a COVID team focused on developing and implementing several safety measures to help our employees manage their work and personal responsibilities, with a strong focus on employee well-being, health and safety. The COVID team established an information campaign to provide employees an understanding of the virus and safety measures, as well as timely updates from governmental regulations.

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There is no guarantee that we will be successful in retaining and attracting key personnel and the replacement of any key personnel could be difficult and time-consuming. The loss of the experience and services of key personnel or the inability to recruit suitable replacements and additional staff could have a material adverse effect on our business, financial condition and results of operations.

Climate change could impact our operating results, access to capital and strategy.

There is an increased attention on greenhouse gas (“GHG”) emissions and climate change from different sectors of society. Argentina agreed the consensus reached in 2015 United Nations Climate Change Conference adopted by consensus the Paris Agreement. The Paris agreement sets a goal to GHG emission reduction and defined targets to limit global temperature increases. International treaties together with increased public awareness related to climate change may result in increased regulation to reduce or mitigate GHG emissions. In addition, if we are unable to follow the pace in which society is moving toward energy transition would adversely impact demand for our services, affecting our results of operations and financial condition.

In addition, environmental laws that may be implemented in the future could increase litigation risks and have a material adverse effect on us. For example, in 2019, the Argentine Congress enacted Law No. 27,520 on Minimal Standards on Global Climate Change Adaptation and Mitigation, which focused on implementing policies, strategies, actions, programs and projects that can prevent, mitigate or minimize the damages or impacts associated with climate change.

Compliance with national and local legal and regulatory changes relating to climate change may in the future increase our costs to operate and maintain our facilities, capital expenditures to install new emission and manage any GHG emissions program may increase our operational expenses. In addition, the effects upon natural gas industry relating to climate change and the resulting regulations and regimes promoting alternative energy resources may also lead to declining demand for natural gas, or Liquids in the long-term.

The physical effects of climate change such as, but not limited to, increases in temperature and sea levels and fluctuations in water levels could also adversely affect our operations and supply chains.

Stakeholder groups are also putting pressure on commercial and investment banks to stop financing fossil fuel companies. According to press reports, some financial institutions have started to limit their exposure to fossil fuel projects. Accordingly, our ability to use financing for these types of future projects may be adversely affected. These factors could have a negative impact on the demand for our products and services and may jeopardize or even impair the implementation and operation of our business, adversely impacting our operating and financial results and limiting our growth opportunities.

Our activities are subject to social and reputational risks, including the potential for protests by members of the local communities.

Although we are committed to maintain good relationships with local communities and to operate our business in a socially responsible manner, we may face opposition from local communities. For example, several of our operations are carried out in the province of Neuquén, Argentina. Local communities, including indigenous communities, often demonstrate in various forms of protest. Such as blocking roads or blocking access, which could indirectly lead to negative impact on commercial activities. Although we consider our relationship with local communities, including indigenous communities to be good, we cannot assure you that any blockade or demands will not impact our operations. These actions could have an adverse effect on our reputation, financial condition and results of operations.  Additionally, if any operational incident occurs that affects those communities we will need to incur in additional costs and expenses in order to restore affected areas and compensate for any damages we may cause. These additional costs may have a negative impact on the profitability of the projects we may decide to undertake.

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The failure of any bank in which we deposit our funds could have an adverse effect on our financial condition.

We currently have cash and cash equivalents deposited and fixed term deposits in several financial institutions significantly in excess of insured levels, including, at times, a significant proportion of our cash balance. For example, with regards to our accounts in the United States, while the U.S. Federal Deposit Insurance Corporation provides deposit insurance of US$250,000 per depositor, per insured bank, the amounts that we have in deposits in U.S. banks far exceed that insurance amount. Therefore, if the U.S. government does not impose measures to protect depositors in the event a bank in which our funds are held fails, we may lose all or a substantial portion of our deposits. We also maintain cash deposits in banks in Argentina and in other countries, some of which are not insured or partially insured by other similar agencies. If any of the financial institutions in which we have deposited funds ultimately fails, we may lose our uninsured deposits at such financial institutions, and/or we may be required to move our accounts to another financial institution, which could cause operational difficulties, such as delays in making payments to our partners and employees, which could have an adverse effect on our business, financial condition, results of operations and cash flows.

Risks Relating to Argentina

We are a stock corporation with limited liability (sociedad anónima) incorporated and organized under the laws of Argentina. Our financial condition and results of operations depend to a significant extent on economic, regulatory and political conditions prevailing in Argentina, the exchange rate between the peso and the U.S. dollar and the reference international prices of Liquids because a significant portion of our revenues (65% of our total consolidated revenues from sales for the year ended December 31, 2022), most of our capital expenditures, almost all of our debt obligations and the cost of natural gas used in our Liquids business are denominated in U.S. dollars, but substantially all of our assets are located in Argentina, and our functional currency is the peso.

Argentina’s public debt may not be sustainable in the near future.

After the primary elections results of August 2019, the international markets casted doubt on Argentina’s debt sustainability. In view of this, the country risk indicator raised to 2,200 basis points, topping-off a depreciation of bond prices. Also, on August 29, 2019 by Decree No. 596/2019 the Government announced a debt profiling consisting of (i) an extension on the payment term for short-term local bonds, only for institutional investors that will receive the full payment over terms of three and six months (15% on the original maturity date, 25% and 60% at 3rd and 6th month of the original maturity date, respectively), but not for natural persons who acquired the bonds before July 31, 2019, who will receive full payment on the maturity date; (ii) a proposal to the Argentine Congress of a bill to extend maturity dates of other local bonds, without reduction on the capital or interest; (iii) a proposal to extend the maturity dates of foreign bonds; and (iv) after achieving fiscal goals, the start of talks with the International Monetary Fund (the “IMF”) in order to reprofile the deadlines to reduce the default risk in 2020 and 2023.

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As a result of the foregoing, Argentina’s credit rating was downgraded in August 2019 and further downgraded in December 2019 to near-default status by both Fitch and S&P after the Government publicly stated that it would delay payments on its short-term dollar-denominated local debt.

Fitch cut Argentina’s long-term issuer rating two notches to “restricted default” from CC, after the Government announced by decree that it would extend payments on US$9.1 billion in dollar-denominated Treasury bills until August 31, 2020. According to Fitch’s criteria, Argentina has defaulted on its sovereign obligations, and this development constitutes a “distressed debt exchange”. S&P also downgraded Argentina’s credit rating to “selective default” from CCC-, while Moody’s foreign issuer rating for Argentina is Caa2.

On June 20, 2018, the IMF’s Executive Board approved the largest stand-by arrangement in the Fund’s history, in support of Argentina’s 2018-21 economic program. After an augmentation in October 2018, access under the arrangement amounted to US$57 billion (1,227% of Argentina’s IMF quota). The program considered only four of the planned twelve reviews, and did not fulfill the objectives of restoring confidence in fiscal and external viability while fostering economic growth. The arrangement was canceled on July 24, 2020.

The economic plan presented by the former administration to access such IMF program sought to strengthen the country’s economy by restoring market confidence through a coherent macroeconomic program that would reduce financing needs, place Argentina’s public debt on a firm downward trajectory and strengthen the plan of inflation reduction through more realistic inflation targets and the strengthening of the BCRA’s independence. The main parts of the economic plan were: (i) the restoration of market confidence, (ii) protection of the most vulnerable segments of society by adjusting the national budget for social protection, (iii) strengthening the credibility of the BCRA inflation targeting framework, and (iv) a progressive reduction of the impossibility of payment.

The government’s decision to extend payments on its short-term notes constitutes the second such delay of payments in five months. In February 2020, the IMF has also publicly stated its concerns about the sustainability of Argentina’s public debt and suggested that a definitive debt operation—yielding a meaningful contribution from private creditors—is required to help restore debt sustainability with high probability. As of the date of this Annual Report, Argentina’s public debt load stands at US$323 billion, including loans from the IMF. Outstanding debt with private bondholders is approximately US$121 billion.

  On April 21, 2020, the Argentine government launched an exchange offer with the aim to refinance its external debt in a way that does not compromise development and Argentina’s growth potential in the coming years. On August 17, 2020, the Argentine government presented its amended bond restructuring offer to the SEC. In August 31, 2020, the Argentine government announced the results of its restructuring bond offer, announcing that the holders owned 93.5% of the principal of the outstanding bonds and that such participation percentage was subsequently increased to 99% by virtue of the application of the collective action clauses of the restructured bonds. After the consummation of its restructuring bond offer, in September 2020 , Moody’s and S&P raised Argentina’s credit rating to CCC, Ca and CCC +, respectively.

On August 8, 2020, Law No. 27,556 on restructuring debt instrumented in public securities denominated in Dollars and issued under Argentine law through a swap operation (Ley N° 27.556 sobre la reestructuración de la deuda pública instrumentada en títulos públicos denominados en Dólares Estadounidenses y emitidos bajo ley argentina mediante una operación de canje). On August 18, 2020 and through Resolution N° 381/2020, the Ministry of Economy began the period of acceptance for the offer of the restructuring, which procedure was detailed in Law No. 27,556 (such Law was in force until September 15, 2020). The “net present value” paid for the securities exchanged was about Ps.53.5 per Ps.100 of face value, discounted at a 10% exit rate, for securities issued during 2015-2019 and about Ps.59.5 for those previously issued in 2005 and 2010. Subsequently, after the end of the early accession period, on September 4, 2020 the Argentine government communicated that the invitation to exchange securities denominated in foreign currency issued under Argentine law had an acceptance equivalent to 98.80% of the total amount of outstanding capital of all eligible securities.

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In addition, the Government has also carried out a debt restructuring which resulted in an exchange premium of 130% and a loss of international reserves of US$1.3 billion to smooth the depreciation of the official exchange rate. Initially, currency controls were partially relaxed and the market responded positively, the premium of the exchange rate was reduced to 85% and the loss of international reserves was drastically reduced.

In addition, on June 22, 2021, the Minister of Economy requested the members of the Paris Club to postpone for one year the payment of US$2,400 million maturing on May 30, 2021. Pursuant to the terms of such agreement, the Argentine Government will make a partial payment of US$430 million in order to avoid the declaration of default, instead of canceling the entirety of the debt. On March 22, 2022 Argentine and the Paris Club agree an extension of this agreement, afterwards, the Argentine Government shall negotiate a complete debt restructuring.

The IMF has held several rounds of meetings with the Government to discuss the recent macroeconomic developments and learn more about the economic plans and policies of the Fernandez Administration. The Argentine authorities are moving to address the difficult economic and social situation facing the country and have implemented a set of policies to address the poverty, while also taking steps to stabilize the economy and secure a sustainable and orderly resolution of Argentina’s debt situation.

In March 2022, the IMF’s executive board approved a 30-month extended fund facility to extend maturities for approximately US$44.1 billion disbursed in 2018 and 2019. The loan aims to provide Argentina with balance of payments and budget support backed by measures designed to strengthen debt sustainability, tackle inflation, boost reserves, address the country’s social and infrastructure gaps and promote inclusive growth, the fund added. Risks to the program are exceptionally high and spillovers from the war in Ukraine may materialize in the short term. This transaction provides funds that will strengthen reserves and allow Argentina to push out payments owed from the 2018 IMF program that failed to stabilize the economy. As part of transaction, the Government has committed to reducing its primary fiscal deficit, weaning off money printing from the central bank and rebuilding reserves, among several objectives.

Finally, on October 12, 2022, the IMF concluded the second review of the agreement, allowing for an immediate disbursement of approximately US$ 3.8 billion.

As of the date of this Annual Report, it is not possible to predict the impact that the measures relating to Argentina’s debt restructuring nor any future economic plan that the Government may implement will have on the Argentine economy. Furthermore, the long-term impact of these measures and any measures future of the current administration in the Argentine economy remains uncertain.

Likewise, the impact of COVID on the main macroeconomic variables and social indicators led the Government to implement a series of measures in order to stabilize the country. As of the date of issuance of this Annual Report, it is not possible to predict the impact that such measures will have and if they will succeed to stabilize the economy and balance the fiscal balance and the trade, inflation, poverty, unemployment and country risk. Any other measure could be detrimental to the economy and adversely affect our business, results of operations and financial situation.

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Moreover, difficulties by Argentina and Argentine issuers in accessing international capital markets continue. Without access to the international financial markets the Government may not have the financial resources to implement reforms and boost growth, which could have a significant adverse effect on the country’s economy and, consequently, on our activities. Failure of Argentina to restructure its debt could cause Argentina to default in the payment of its public debt, which could materially and adversely affect our business, financial condition and results of operation, and our ability to meet our financial obligations, as it could have a direct impact on our customers’ ability to pay for our products and services, the demand for energy and our ability to access local and international markets to finance our operations and our growth. In addition, we cannot predict the outcome of any future restructuring of Argentine sovereign debt.

Argentina’s fiscal situation could limit the country’s access to the capital market and adversely affect the Argentine economy.

In recent years, Argentina has substantially increased public expenditure. In 2016, government spending increased by 42.8% as compared to 2015, resulting in a primary fiscal deficit of 4.2% of GDP for 2015. In 2017, government spending increased by 25.9% as compared to 2016, resulting in a primary fiscal deficit of 3.8% of GDP for 2017. In 2018, government spending increased by 13.1% as compared to 2017 resulting in a primary fiscal deficit of 2.4% of GDP for 2018, but while the primary fiscal deficit decreased compared to 2017, the financial deficit (interest rates of the international debt with IMF) increased to 2.8%, resulting in a total deficit of 5.2% for the year 2018. In 2019, government spending increased by 36.2% as compared to 2018, resulting in a primary fiscal deficit. In 2020, government spending increased by 52.7% as compared to 2019 resulting in a primary fiscal deficit. In 2021, government spending increased by 77% as compared to 2020.

In addition, because of the economic impact of COVID and the national quarantine, in order to stimulate the economy and meet the needs of the neediest sectors of the population, the Argentine government has considerably increased public spending. In this sense, the Argentine government adopted various measures to finance such public spending, including, among other things, others, the use of the resources of the BCRA and ANSES, and has used the issuance of money as fundraising tool. The primary fiscal deficit for 2021 turned out to be 3% in GDP terms.

Argentina’s primary fiscal deficit reached 2.4% of GDP in 2022. Thus, the government reached the target set forth in the agreement with the IMF and reduced the imbalance in the public accounts in 2021.

The increase in public spending occurs due, for example, to the benefits of the security social, financial aid to provinces with financial problems and increased spending on public works and subsidies, including subsidies to the energy and transport sectors.

Further deterioration of fiscal accounts could negatively affect government capacity to access long-term financial markets.

In relation to the agreement signed with the IMF in 2018, the Macri government committed to address fiscal solvency and therefore took steps to curb the fiscal deficit through the reduction of gas and transportation subsidies and other expenses. Similar measures to reduce Argentina’s fiscal deficit were agreed in the most recent IMF agreement. In the past, these policies have caused a rise in prices and thus have had a negative impact on the power purchasing power of consumers. After taking office in 2019, the current government, within the framework of the Solidarity Law, serving the most vulnerable sectors, have taken a series of measures that have slowed the reduction of public spending.

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The application of new measures in the future could also have negative effects. In addition, the federal government’s primary fiscal balance could be adversely affected if public spending increases faster than income in the future. On the other hand, weaker fiscal results than expected in Argentina could have a material adverse effect on the economy of this country.

The Government’s ability to access the long-term financial markets to finance such deficit is limited given the high levels of public sector indebtedness. The inability to access the capital markets to fund its deficit or the use of other sources of financing may have a negative impact on the economy and could limit the access to such capital markets for Argentine companies, which could adversely affect our business, financial condition and results of operations.

Certain risks are inherent in any investment in a company operating in an emerging market such as Argentina.

Argentina is an emerging market economy and investing in emerging markets generally carries risks. According to a statement from MSCI Inc., Argentina was considered an emerging market until June 2021, when it was reclassified as stand-alone market. According to MSCI index countries classified as stand-alone markets are those that are currently partially or fully closed to foreign investors, where stock lending and short selling are activities that are either not developed or completely prohibited, with small capital markets and political tensions.

Risks include political, social and economic instability that may affect Argentina’s economic results, which can stem from many factors. In general, Argentine economic conditions are dependent on a variety of factors, including, but not limited to, the following: (i) domestic production, international demand and prices for Argentina’s principal export commodities, (ii) the competitiveness and efficiency of domestic industries and services, (iii) the stability and competitiveness of the peso against foreign currencies and exchange controls, (iv) high interest and inflation rates, (v) Argentina’s fiscal and trade deficits, (vi) Argentina’s public debt level, (vii) foreign and domestic investment and financing, (viii) governmental policies and the legal and regulatory environment, including import and export contracts and tax provisions, (ix) consumption levels, (x) wage and price controls and (xi) political uncertainty and social unrest.

Government policies and regulation— which at times have been implemented through informal measures and have been subject to radical shifts— that have had a significant impact on the Argentine economy in the past have included, among others: (i) monetary policy, including exchange controls, capital controls, high interest rates and a variety of measures to curb inflation; (ii) restrictions on exports and imports; (iii) price controls; (iv) mandatory wage increases and prohibition of dismissals; (v) taxation; and (vi) government intervention in the private sector.

Any of these factors, as well as volatility in the capital markets, may adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

Economic volatility in Argentina has adversely affected and may continue to adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

Our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations depend to a significant degree on macroeconomic, political, regulatory, and social conditions in Argentina. The Argentine economy has experienced significant volatility in recent decades, characterized by periods of low or negative growth, high and variable levels of inflation and interest rates and currency devaluation. As a consequence, our business and operations have been, and could in the future be, affected from time to time, to varying degrees, by the high volatility in Argentina, which primarily results from economic and political developments and other material events affecting the Argentine economy, such as: inflation, price controls, fluctuations in foreign currency exchange rates and interest rates; currency devaluation; governmental policies regarding tariffs, spending and investment, and other regulatory initiatives increasing government involvement with economic activity; and international conflicts, social unrest and insecurity concerns.

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In 2020, 2019 and 2018, the peso experienced a rapid devaluation against major foreign currencies, particularly against the U.S. dollar. In 2019, immediately after the preliminary presidential elections (elecciones primarias, abiertas, simultáneas y obligatorias), the peso suffered a significant devaluation. According to the exchange rate information published by the Banco Nación, the peso depreciated by 22.1% against the U.S. dollar during the year ended December 31, 2021 (compared to 40.5%, 58.9% and 102.2% in the years ended December 31, 2020, 2019, and 2018). During 2022, the peso depreciated 72.5% against the U.S. dollar.

As a result of the peso’s increased volatility, in 2019 the Government announced several measures to control and restrict the ability of companies and individuals to exchange pesos for foreign currencies. Those measures include the requirement to obtain prior approval from the BCRA, which could eventually restrict the ability to exchange pesos for other currencies. Moreover, restrictions also apply to the acquisition of any foreign currency for holding as cash within Argentina and to transfer dividends abroad, among others. Additionally, the Government implemented a new tax at a rate of 30% on certain transactions involving the acquisition of foreign currency. For additional information see “Item 10. Additional Information—D. Exchange Controls.”

The ability of the Government to stabilize the foreign exchange market and restore economic growth is subject to uncertainty. The continued depreciation of the peso could have a material adverse effect on Argentina’s economy and, consequently, our business, results of operations and financial condition.

In addition, this rapid devaluation has confronted inflationary pressures, evidenced by significantly higher fuel and food prices, among other indicators. Inflation in Argentina has contributed to a material increase in our operating costs, in particular labor costs, and negatively affected our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations. There can be no assurance that inflation rates will not escalate in the future, and the effects of measures adopted or that may be adopted in the future by the Government to control inflation are uncertain. See “—Government intervention in the Argentine economy could adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations” and “—High levels of inflation could negatively affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.”

The Argentine economy remains vulnerable, as reflected by the following economic conditions:

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• inflation, which remains high, and may continue to be high in the future;

• volatility in real GDP, which according to the restated information released by INDEC grew by 2.7% in 2015, decreased by 2.1% in 2016, grew by 2.7% in 2017, decreased by 2.5% in 2018, decreased by 2.2%, 9,9% in 2019 and 2020, respectively. In 2021 the GDP increase 10.3% and in 2022 5.2%.

• Argentina’s public debt as a percentage of GDP, which remains high, and as of September 30, 2022, represented approximately 79.8% of the GDP;

• the discretionary increase in public expenditures that has resulted (and continues to result) in a fiscal deficit;

• high unemployment and informal employment rates;

• high exchange rate volatility;

• high fiscal and trade deficits;

• an inability to pay public debt and the reperfilation of debt maturities;

• limited access to funding in the local and international capital markets;

• agricultural exports, which fueled the economic recovery, have been affected by drought and lower prices than in prior years;

• fluctuations in international oil prices;

• unavailability of long-term credit to the private sector;

• the effects of a restrictive U.S. monetary policy, which could generate an increase in financial costs for Argentina;

• reduction in the BCRA’ s foreign currency reserves;

• uncertainty with respect to the imposition of exchange and capital controls;

• the abrupt fall in the value of sovereign bonds and a decline in consumer confidence or foreign direct investment;

• the public health concerns derived from COVID, and its scale and duration discussed below, which remain uncertain, but could impact our earnings, cash flow, liquidity, and financial condition; and

• other political, social and economic events outside of Argentina that adversely affect the current growth of the Argentine economy.

The current administration had to take a series of economic and health measures, given the economic context generated by COVID, not being able to reverse the fall in the GDP registered in the last years. It is not yet clear if these are policies can be sustained and the effects these measures will have on the fiscal position of the country and the economy in general.

A decline in international demand for Argentine products, a lack of stability and competitiveness of the peso against other currencies, a decline in confidence among consumers and foreign and domestic investors, a high rate of inflation and future political uncertainties, among other factors, may affect the development of the Argentine economy which could lead to reduced aggregate demand and adversely affect our business, financial condition and results of operations.

As of the date of this Annual Report, the impact of the policies and measures adopted by the Government on the Argentine economy as a whole cannot be predicted. Also, we cannot predict the full future impact that changes in the application of the tax indexation procedure and related adjustments will have on our financial statements, or the effects on our effective tax rate or on our business, results of operations and financial condition. The factors described above, among other factors, may materially and adversely affect the development of the Argentine economy, which could adversely affect our business, financial condition and results of operations.

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The ongoing political instability in Argentina may adversely affect the Argentine economy.

Argentina’s political and social environment has historically influenced, and continues to influence, the performance of the country’s economy. Political and social crises have affected and continue to affect the confidence of investors and the public, which has historically resulted in economic deceleration and heightened volatility in securities with underlying Argentine risk. The recent political instability in Argentina has contributed to a decline in market expectations and forecasts for the Argentine economy. The Market Expectations Survey (“REM”) issued by the BCRA still shows high levels of inflation and exchange rate evolution and activity indicators that have not yet managed to achieve economic recovery. This suggests that the weak macroeconomic conditions in Argentina may continue in the upcoming years.

The Argentine economy is also particularly sensitive to local political developments. Presidential elections take place in Argentina every four years and legislative elections every two years, resulting in the partial renewal of both chambers of Congress.

According to the corresponding authorities, the primary elections (elecciones primarias, abiertas, simultáneas y obligatorias) for president and legislative elections are scheduled for August 13, 2023 and the general elections is scheduled for October 22, 2023.

The result of presidential, as well as legislative, mid-term and full term elections may lead to changes in government policies that impact upon the Company.

We cannot provide any assurance that future economic, social and political developments in Argentina, over which we have no control, will not impair our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

The Solidarity Law and the measures that the new administration has implemented could adversely affect our results of operations and financial condition.

The Solidarity Law granted the Executive Branch broad legislative powers to ensure the sustainability of the public debt, regulated the tariff restructuring of the energy system through a renegotiation of the RTI and reordered the regulators of the energy system, among others. Likewise, the rates of public utilities for natural gas remain unchanged for a maximum period of 180 days (since December 23, 2019), which period has been extended until the RTI process concludes or the transitional tariff increase is put into effect. See “—Risks Relating to Our Business—Failure or delay in the implementation of tariff increases could have a material adverse effect on our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations. In addition, our inability to obtain tariff adjustments reflecting the increase in operating cost could harm the development of our Natural Gas Transportation business segment” for additional information of the current RTI.

This law also modified certain tax aspects previously modified by the administration of Mauricio Macri. As a result, the tax rate on personal property has been increased, a new 30% currency purchase tax has been created, and the previous changes in the income tax rates have been reversed, suspending the 25% reduction for the year beginning on January 1, 2020 and providing that the result of the tax inflation adjustment must be paid in six installments, instead of three installments, as previously established.

Additionally, and in order to meet the fiscal deficit, the pension adjustment system has been suspended by the Solidarity Law and finally modified by Law No. 27,609.

It is not possible to foresee the impact of this law or the measures that could be taken by the new administration at the national or provincial level, and the effect that such measures could have on the Argentine economy and on Argentina’s ability to meet its financial obligations, which could negatively affect our business, financial condition and results of operations. In addition, we cannot assure you that economic, regulatory, social and political events in Argentina will not affect our business, financial condition or the results of our operations.

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Public health threats could have an adverse effect on the Argentine economy and on our business, financial condition or results of operations.

On March 11, 2020, the World Health Organization declared COVID a pandemic. In response, countries have adopted extraordinary measures to contain the spread of the virus, including imposing travel restrictions and closing borders, requiring closures of non-essential businesses, instructing residents to practice social distancing, issuing stay-at-home orders, implementing quarantines and similar actions. The ongoing pandemic and these extraordinary government measures are disrupting global economic activity and resulting in significant volatility in global financial markets. According to the IMF, the global economy has recently entered into a recession.

The Government adopted multiple measures in response to the COVID pandemic, including nationwide mandatory lockdowns. The Government has also required from time to time the mandatory shutdown of businesses not considered essential (oil and gas activities are among those considered essential and exempt from lockdown measures). COVID cases have recently risen since the last quarter of 2021 in several regions of the world as a result of the new COVID variants, in particular the Omicron and Delta variants.

In order to mitigate the economic impact of the COVID pandemic and mandatory lockdown and shutdown of non-essential businesses, the Argentine government has adopted social aid, monetary and fiscal measures. We cannot assure you whether these measures will be sufficient to prevent a severe economic downturn in Argentina, particularly if current conditions are prolonged and if Argentina’s main trading partners are concurrently facing an economic recession. However, the Government may have more limited resources at this time to support the country’ s economy; the pandemic has struck at a time when Argentina is simultaneously struggling to emerge from a two-year recession.

These temporary measures included the issuance of stay-at-home orders, closures of non-essential businesses, prohibition of layoffs without cause and suspension of workers, among others. Although these measures may help attenuate the economic impact on the Argentine economy overall, they may have a negative impact on our business and results of operations.

Although a rebound effect on economic activity was foreseeable, after the quasi-closed economy for several consecutive months as a result of the sanitary restrictions imposed due to the Covid pandemic, the improvement in the international prices of the products of Argentina’s exportable basket, the approval and massive use of vaccines - especially in the second half of the year - which allowed a greater reduction in health restrictions and the extraordinary inflow of funds as a stimulus measure from the IMF to help countries solve the effects of Covid, generated that the recovery has been greater than expected. anticipated at the beginning of the year. The GDP grew by 10.3% in 2021 and 5.2% in 2022.

Additionally, we face various risks arising from the economic impact of the pandemic and government measures which are difficult to predict accurately at this time, such as:

• The situation generated by COVID could cause a decrease in our revenues (i.e. A reduction in the demand of our Liquids products) or an increase in our operating costs. As a result of financial turmoil in Argentina caused by disruptions in supply chains and public debt restructuring, we may experience difficulties in our ability to pay off our debts and other financial obligations as they become due. We could also face difficulties in accessing debt and capital markets and may be forced to refinance our indebtedness; and

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• An extended period of remote work by our employees could deplete our technological resources and result in or exacerbate certain operational risks, including an increased risk of cybersecurity. Remote work environments may be less secure and more susceptible to hacking attacks, including phishing and social engineering attempts to exploit the COVID pandemic.

In addition, governmental authorities may recommend or impose additional measures that could cause further significant disruptions to business activity in general. We have also modified some of our business activities by changing our cleaning procedures, implementing remote work modalities and suspending certain business activities. The impact of the COVID on the financial markets has also negatively affected borrowing costs, hedging activities, liquidity and access to capital in general, which could limit our ability to obtain financing for our operations on a timely basis, on acceptable terms or at all.

In addition, the slowdown in economic activity caused by COVID and other internal factors and ongoing changes in customer habits may result in a decrease in energy demand even after the government measures have been lifted.

We are continuously monitoring the impact of the ongoing COVID pandemic on our Company. The ultimate impact of the pandemic on our business, results of operations and financial condition remains highly uncertain and will depend on future developments outside of our control, including the intensity and duration of the pandemic and the government measures taken in order to contain the virus or mitigate the economic impact. To the extent the COVID pandemic adversely affects our business, it may also have the effect of heightening many of the other risks described in this “D.Risk Factors” section.  For additional information regarding the impact of COVID on our results and financial situation, see “Item 5. Operating and Financial Review and Prospects—A. Operating Results.”

High levels of inflation could negatively affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

Pursuant to Argentine law, the INDEC is the only institution in Argentina entitled to publish official nationwide statistics. In addition, inflation has undermined the Argentine economy and the Government’s ability to stimulate economic growth. In the past, there have been concerns regarding the accuracy of the INDEC statistics. In 2007, the INDEC changed the way it calculated inflation statistics such as CPI and WPI.

In the past, due to the lack of accuracy of the INDEC statistics, the IMF executive board issued a declaration of censure against Argentina in connection with Argentina’s breach of its obligations to provide information to the IMF under the Articles of Agreement and called on Argentina to adopt remedial measures to address the inaccuracy of inflation and GDP data without further delay. The uncertainty relating to the inaccuracy of the economic indexes and rates may lead to a lack of confidence in the Argentine economy and may, in turn, limit our ability to access credit and capital markets, which could adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

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High inflation rates affect Argentina’s foreign competitiveness and social and economic inequality, negatively impact employment, consumption and the level of economic activity, and undermine confidence in Argentina’s banking system, which could further limit the availability of and access by local companies to domestic and international credit. Inflation rates could escalate in the future, and there is uncertainty regarding the effects that the Government’s measures to control inflation may have. Increased inflation could adversely affect the Argentine economy, which in turn may have an adverse effect on our business, financial condition and results of operations.

Inflation has, in the past, materially undermined the Argentine economy and the government’s ability to foster conditions that would permit stable growth. Currently, Argentina faces inflationary pressures, evidenced by significantly higher fuel, energy and food prices, among other factors. Increases in inflation rates could accelerate in the future, and there is uncertainty regarding the effects that the measures adopted, or that may be adopted in the future, by Argentina to control inflation may have.

The CPI variation for the year ended on December 31, 2022, was 94,8%.

As discussed elsewhere in this Annual Report, given that the Argentine economy has been considered as hyperinflationary, since July 1, 2018, we have applied IAS 29 in our Financial Statements, which requires that the financial statements of an entity whose functional currency is that of a hyperinflationary economy, regardless of whether they are based on the historical cost method or the current cost method, be expressed in terms of the current unit of measurement at the reporting date of the reporting period. See “—Presentation of Financial and Other Information—Financial Statements and Basis of Preparation.”

In recent years, the Government has taken certain measures to curb inflation, such as implementing price controls and limiting wage increases. We cannot assure you that inflation rates will not continue to increase in the future or that any measures taken or that may be taken by the Fernández administration to control inflation will be effective or successful. High inflation rates continue to be a challenge for Argentina. Significant increases in inflation rates could have a material adverse effect on Argentina’s economy and, in turn, could increase our operating costs, in particular labor costs, and could adversely affect our business, financial condition and results of operations.

Because Natural Gas Transportation business segment sales represented 25% of our total revenues during the year ended December 31, 2022, and are denominated in pesos, any further increase in the rate of inflation not accompanied by a parallel increase in our tariffs would decrease our revenues in real terms and adversely affect our results of operations. Further, as a consequence of the application of IAS 29, maintaining monetary assets generates loss of purchasing power; provided that such items are not subject to an adjustment mechanism that compensates to some extent such loss. This loss is booked in the statement of comprehensive income.

Restrictions on transfers of foreign currency and the repatriation of capital from Argentina may impair our ability to pay dividends or imports and investors may face restrictions on their ability collect capital and interest payments in connection with corporate bonds issued by Argentine companies.

The Argentine government and the BCRA have implemented certain measures that control and restrict the ability of companies and individuals to access to the foreign exchange market.  Those measures include, among others: (i) payment of imports and other purchases of goods abroad, (ii) purchase of foreign currency by residents with specific application, (iii) payment of profits and dividends, (iv) payment of capital and interest on financial indebtedness, among others, the entity shall have the prior consent of the BCRA unless it has an affidavit from the client stating that at the time of access to the exchange market: (i) all of its foreign currency holdings in the country are deposited in accounts in financial institutions and that it does not have liquid external assets available; and (ii) undertakes to liquidate on the exchange market, within five working days of its making available, those funds that it receives abroad arising from the collection of loans granted to third parties, the collection of a term deposit or the sale of any type of asset, where those funds have been acquired after May 28 2020.

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As a result of the tightening of exchange controls, the difference between the official exchange rate, which is currently used for commercial and financial transactions, and other secondary exchange rates that implicitly arose as a result of certain transactions commonly carried out in the capital market (“MEP” or “contado con liquidación” dollar) widened considerably, creating a gap of approximately 94% with the official exchange rate as of December 31, 2022. The Government could maintain a single official exchange rate or create multiple exchange rates for different types of transactions, substantially changing the exchange rate at which we purchase foreign currency to repay its foreign currency denominated indebtedness. In addition, the imposition by the government of additional exchange controls and restrictions and/or other measures in response to capital outflows or devaluation of the Peso could weaken public finances. Such a weakening of public finances could have an adverse effect on our results of operations and financial condition.

For additional information see “Item 10. A. Exchange Controls.”

As of the date of this Annual Report, the restrictions outlined above remain in place. Such measures may negatively affect Argentina’s international competitiveness, discouraging foreign investments and lending by foreign investors or increasing foreign capital outflow which could have an adverse effect on economic activity in Argentina, and which in turn could adversely affect our business and results of operations. Any restrictions on transferring funds abroad imposed by the government could undermine our ability to pay dividends on our ADSs in U.S. dollars. Furthermore, these measures may cause delays or impose restrictions on the ability to collect payments of capital and interest on bonds issued by us. The challenge will be to achieve acceptance by creditors, in accordance with the BCRA regulations mentioned above, especially when it has highly diversified and retail creditors.

Fluctuations in the value of the peso may also adversely affect the Argentine economy, our financial condition and results of operations.

Since January 2002, the peso has fluctuated significantly in value and generally depreciated against the U.S. dollar, with adverse consequences to our business. A substantial increase in the value of the peso against the U.S. dollar could also present risks for the Argentine economy, since it may lead to a deterioration of the country’s current account balance and the balance of payments. Between 2011 and December 2015, the Government strengthened exchange controls in response to an increase of capital outflows as compared to inflows and to a drop in the commercial surplus. However, these controls were not able to prevent the decrease of the international reserves of the BCRA between 2012 and 2015. In the past, a decrease in the BCRA’s reserves resulted in Argentina being vulnerable to inflation and external shocks, affecting the country’s capacity to overcome the effects of an external crisis.

After several years of moderate fluctuations in the exchange rate, on December 17, 2015, Macri’s administration implemented certain measures, including the lifting of most of the foreign exchange controls. After these measures were taken, the value of the peso could freely fluctuate against the U.S. dollar.

Subsequently, in May 2018, the peso experienced a rapid devaluation against the main foreign currencies, particularly the U.S. dollar. As a result of the greater volatility of the peso, the Government announced several measures to restore market confidence and stabilize the value of the peso. In this regard, on December 31, 2018, the exchange rate of the U.S. dollar increased by 102.1%, from Ps.18.649 to Ps.37.7.

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After the primary elections (elecciones primarias, abiertas, simultáneas y obligatorias) held in August 2019, the peso experienced again a rapid devaluation against the main foreign currencies, particularly the U.S. dollar. Since then, the Government has imposed several restrictions on the foreign exchange market. An unofficial U.S. dollar trading market has developed in which the peso/U.S. dollar exchange rate is significantly higher than the rate in the foreign exchange market.

As a consequence of the imposition of exchange controls, the spread between the official exchange rate and other secondary exchange rates implicitly resulting from certain common capital market transactions has widened significantly, reaching a value of more than 100% in October 2020.

As of December 31, 2022, the total amount of principal and accrued but unpaid interest under our consolidated U.S. dollar-denominated indebtedness was US$534 million.

We cannot predict the future exchange rate between peso and the U.S. dollar, or how any fluctuation may affect our operational costs denominated in U.S. dollars.

Further depreciation of the peso against the U.S. dollar would likely result in a material adverse effect on our business because of our exposure to financial debt in U.S. dollars. In addition, future devaluations could result in higher inflation, reduce real wages and adversely affect the Government’s ability to honor its foreign debt obligations. The depreciation of the Peso can also negatively impact businesses whose success is dependent on domestic market demand, and adversely affect the Government’s ability to honor its foreign debt obligations.

A substantial increase in the exchange rate of the Peso against foreign currencies of the Peso against the U.S. dollar also represents risks for the Argentine economy since it may lead to a deterioration of the country’s current account balance and the balance of payments which may have a negative effect on GDP growth and employment, and reduce the revenue of the Argentine public sector by reducing tax revenue in real terms, due to its current heavy dependence on export taxes.

The impossibility of addressing the actual and potential risks of institutional deterioration and corruption, the economy and the financial situation of Argentina has been affected negatively and could continue to be.

Argentina is ranked 78 out of 180 in Transparency International’s 2020 Corruption Perceptions Index and 126 of 190 in the World Bank’s Doing Business 2020 report. The lack of a solid and transparent institutional framework for contracts with the Argentine government and its agencies and accusations of corruption have affected and could affect negatively to Argentina.

Likewise, at the date hereof, other ongoing investigations into complaints of money laundering and corruption are underway.

Recognizing that the failure to address these issues could increase the risk of political instability, distort decision making processes and adversely affect Argentina’s international reputation and ability to attract foreign investment, the Macri administration announced several measures aimed at strengthening Argentina’s institutions, enhancing the integrity of public officials and reducing corruption. These measures included the reduction of criminal sentences in exchange for cooperation with the government in corruption investigations, increased access to public information, the seizing of assets from corrupt officials, increasing the powers of the Anticorruption Office (Oficina Anticorrupción) and the passing of a new public ethics law, among others. The Government’s ability to implement these initiatives is uncertain.

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There can be no assurance that the implementation of these measures by Argentina will be successful or even sufficient in strengthening Argentina’s institutions, enhancing the integrity of public officials, stopping institutional deterioration and preventing corruption. We cannot control or predict whether such investigations or allegations will lead to further political or economic instability or whether new allegations against government officials, members of the Argentine Congress, judges or owners or officers of other companies will arise, nor can we predict the outcome of any such allegations and their effect on the Argentine economy, which may be adverse.

Government intervention in the Argentine economy could adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

The Argentine government has historically exercised significant influence over the economy, and public services companies in particular have operated in a highly regulated environment. Our business and operations have been, are and could in the future be affected by actions taken by the Government through the implementation of new or amended laws and regulations, such as nationalizations, expropriations, forced divestiture of assets, amendments to or renegotiation or revocation of a license, restrictions on production, imports and exports, exchange and/or transfer restrictions, including those relating to dividend payments, direct and indirect price controls, tax increases, changes in the interpretation or application of tax laws and other retroactive tax claims or challenges, cancellation of contractual rights and delays or denials of governmental approvals.

There have been examples of government intervention in the economy, including through the implementation of expropriation and nationalization measures, price controls and exchange controls.

In 2008, the Government absorbed and replaced the former private pension system with a public “pay as you go” pension system. As a result, all resources administered by the private pension funds, including significant equity interests in a wide range of listed companies, were transferred to a separate fund (Fondo de Garantía de Sustentabilidad or “FGS”) to be managed by the Administración Nacional de la Seguridad Social (“ANSES”). ANSES is entitled to designate government representatives to the boards of directors of these companies. The nationalization of Argentina’s pension and retirement system was a change significant in the Argentine government’s approach to the main public companies. FGS currently holds 24.0% of our outstanding capital stock and has two representatives on our Board of Directors. On November 19, 2020, Law 27,574 was published in the Official Gazette, which regulates the role of the representatives of the FGS in those companies in which it has a stake, providing that the FGS will dictate the rules that are necessary in order to regulate their appointment, function, responsibility, performance and remuneration, which has been regulated by Decree No. 1041/2020 and ANSES Resolution No. 57/2021.

For additional information regarding rules and regulations that govern our relationship with FGS, see “Item 7. Major Shareholders and Related Party Transactions.”

In 2012 and again in 2013, the Argentine Congress established new regulations providing for increased intervention in the capital markets by the Government. On May 9, 2018, the Macri administration approved an amendment to the Law of Productive Financing, including amendments to the Capital Markets Law of Argentina No. 26,831 (the “Capital Markets Law”), which, among other things, limited the scope of intervention by the CNV in public companies.

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In the recent past the Government has also adopted numerous measures to directly or indirectly control the access by private companies and individuals to foreign trade and foreign exchange markets, such as restricting free access to these markets and imposing the obligation to repatriate and sell within the local foreign exchange market all foreign currency revenues obtained from exports. These regulations have been recently reinstated, preventing or limiting us from offsetting the risk derived from our exposure to the U.S. dollar and the access to foreign exchange market.

Historically, actions of the Government concerning the economy, including decisions regarding interest rates, taxes, price controls, wage increases, increased benefits for workers, exchange controls and potential changes in the market of foreign currency, have had a substantial adverse effect on Argentina’s economic growth. A low-growth and high-inflation rates scenario continues and is likely going forward, as a result of the accumulation of macroeconomic imbalances over recent years, the actions of the Government in regulatory matters and challenging conditions in the international economy. We can offer no assurance that policies implemented by the Government will not adversely affect our business, results of operations and financial condition, the value of our securities, and our ability to meet our financial obligations.

Recently, on March 22, 2023, the Ente Nacional Regulador de la Electricidad (“ENRE”) announced the 180-days intervention of EDESUR, the second largest power distributor of the country with approximately 2.5 million customers, due to the repeated blackouts in the Buenos Aires area.

In such regards, the current administration also took several other measures to reduce the impact of public service tariffs on the economy. These measures included the freezing of tariffs, the pesification of electricity generation rates, and deferral of the payment of natural gas bills for certain consumers, among others. For additional information see “Item 4. Our Information—B. Business Overview.—Natural Gas Transportation.”  In addition, the Executive Branch declared the intervention of the ENARGAS until December 31, 2023.

As of the date of this Annual Report, we cannot predict the results or impact of these measures on the hydrocarbons development in Argentina. We are also unable to predict whether the Government will take any additional measures that may negatively affect Argentina’s hydrocarbons market.

Argentina is an emerging market economy that is highly sensitive to local political developments that have had an adverse impact on the level of investment in Argentina and the access of Argentine companies to the international capital markets. Future developments may adversely affect Argentina’s economy and, in turn, our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

We cannot provide any assurance that we will be able to access foreign exchange markets or that these measures will not cause fluctuations in the value of the peso. The setting of certain exchange controls and other future economic, social and political developments in Argentina, over which we have no control, may adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations. For additional information on developments relating to exchange controls, see “Item 10. Additional Information—D.  Exchange Controls.”

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The Argentine economy may be adversely affected by economic developments in other markets and by more general effects, which could have a material adverse effect on Argentina’s economic growth.

Argentina’s economy is vulnerable to external shocks that could be caused by adverse developments affecting its principal trading partners and emerging markets. A significant decline in the economic growth of any of Argentina’s major trading partners (including Brazil, the European Union, China and the United States) as a result of the COVID pandemic is having a material adverse impact on Argentina’s trade balance and, therefore, adversely affect Argentina’s economic growth. Economic slowdowns have led to declines in Argentine exports in the last few years. Specifically, fluctuations in the price of the commodities sold by Argentina and a significant revaluation of the peso against the U.S. dollar could harm Argentina’s competitiveness and affect its exports.

The economy in Brazil, one of the main import and export markets for Argentina, has experienced rising negative pressure because of political uncertainty and the effects of the COVID, putting pressure on the products that Argentina exports to that country and its competitiveness. Argentine foreign trade is highly dependent on the Brazilian economy; thus, a poor performance of Brazil’s economy could lead to the deterioration of Argentina’s trade balance. Additional Brazilian political and economic crises could negatively affect the Argentine economy.

Financial and securities markets in Argentina are also influenced by economic and market conditions in other markets worldwide. U.S. monetary policy has significant effects on capital inflows and asset price movements in emerging market economies. Increases in U.S. interest rates result in the appreciation of the U.S. dollar and decreases in prices for raw materials, which can adversely affect commodity-dependent emerging economies.

Additionally, a slowing of China’s GDP growth has led to a reduction in exports to this Asian country, which in turn has caused oversupply and price declines in certain commodities. Decreases in exports have a material adverse effect on Argentina’s public finances due to the loss of taxes on exports, causing an imbalance in the country’s exchange market.

On January 31, 2020, the United Kingdom left the European Union on the terms of the withdrawal agreement concluded between the United Kingdom and the EU Council. The withdrawal agreement allowed for a transition period during which the United Kingdom’s trading relationship with the European Union remained largely unchanged. This transition period ended on December 31, 2020. The European Parliament approved the EU-UK Trade and Cooperation Agreement while the European Council has already approved the provisional application of the agreement. As of the date of this Annual Report, uncertainty remains over the United Kingdom’s future relationship with the European Union. The continued uncertainty over the Brexit process has caused, and is anticipated to continue to cause, volatility in the financial markets, which may in turn have a material adverse effect on our business, financial condition and results of operations.

In 2022 the world faced a range of macro challenges including the war in Ukraine, post-COVID supply chain constraints, inflationary pressures and risk of global recession. During the year, U.S. Federal Reserve increased its target reference rate to relieve inflationary pressure which had a negative impact in the cost of credit for emerging markets.

Although economic conditions vary from country to country, investors’ perceptions of events occurring in other countries have in the past substantially affected, and may continue to substantially affect, capital flows into and investments in securities from issuers in other countries, including Argentina. International investors’ reactions to events occurring in one market sometimes demonstrate a “contagion” effect, in which an entire region or class of investment is disfavored by international investors. Argentina could be adversely affected by negative economic or financial developments in other countries, which in turn may have an adverse effect on our financial condition and results of operations.

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Certain economic policies of the former government administration in Argentina, including foreign exchange restrictions, led in the past to a reduction in exports and foreign direct investments, to a decline in national tax revenues and to an inability to access international capital markets. There can be no assurance that the Argentine financial system and securities markets will not be adversely affected by policies that may be adopted by the government in the future or by events in the economies of developed countries or in other emerging markets. A slowdown in economic activity in Argentina would adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

Argentina’s past default and litigation with holdout bondholders may limit our ability to access international markets.

Argentina’s history of defaults on its external debt and the protracted litigation with holdout creditors, summarized below, may reoccur in the future and prevent Argentine companies such as us from accessing the international capital markets readily or may result in higher costs and more onerous terms for such financing, and may therefore negatively affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

Following the default on its external debt in 2001, Argentina sought to restructure its outstanding debt by offering holders of the defaulted bonds two opportunities to exchange them for newly issued debt securities, in 2005 and again in 2010. Holders of approximately 93% of Argentina’s defaulted debt participated in the exchanges. Nonetheless, a number of bondholders held out from the exchange offers and pursued legal actions against Argentina in the courts of the United States and several other countries.

After almost 15 years of litigation, and following the beginning of Mr. Macri’s administration, in February 2016, Argentina negotiated and reached settlement agreements with almost all of its holdout creditors. As required by the settlement, on March 31, 2016, the Argentine Congress voted to repeal Law No. 26,017 (known as Ley Cerrojo) and Law No. 26,984 (known as Ley de Pago Soberano), which prohibited Argentina from offering to the holdouts better conditions than those offered in the debt swaps of 2005 and 2010. On April 13, 2016, Argentina announced that it would proceed with a new bond offering of up to US$12.5 billion to repay the holdouts. After issuing US$16.5 billion of new bonds to international investors, on April 22, 2016, Argentina notified the competent U.S. court that it had made full payment under the settlement agreements with the holdout creditors. Although the size of the claims involved has decreased significantly, litigation initiated by bondholders that have not accepted Argentina’s settlement offer continues in several jurisdictions.

However, even though Argentina has successfully accessed the international capital markets since the settlement, there continues to be a risk that the country will not attract the foreign direct investment and financing needed to restart the investment cycle and achieve sustainable rates of economic growth. If that occurs, Argentina’s fiscal condition could be adversely affected, which could lead to more inflation and undermine the government’s ability to implement economic policies designed to promote growth. The difficulty of sustaining economic growth over time with reasonable price stability could result in a renewed episode of economic instability.

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In addition, the foreign shareholders of several Argentine companies (including us), together with public utilities and certain bondholders that did not participate in the exchange offers described above, filed claims with the International Center for Settlement of Investment Disputes (“ICSID”), alleging that the emergency measures adopted by the Government in 2002 did not meet the just and equal treatment requirements of several bilateral investment treaties to which Argentina is a party. Several of these claims have been resolved against Argentina. Claimants have also filed claims before arbitral tribunals under the rules of the United Nations Commission on International Trade Law (UNCITRAL) and under the rules of the International Chamber of Commerce. Several awards have been issued against Argentina and several cases are still ongoing.

Moreover, difficulties in accessing Argentina’s international credit may have an impact on our company as the Argentine government postponed the maturity dates of its bonds and cut interest rates.

Also, ongoing situations, such as the claims before the ICSID, and the economic policy measures adopted by the Government, or any future default of Argentina regarding its financial obligations may harm Argentine companies’ ability to obtain financing. Financial conditions of such access could be disadvantageous to Argentine companies and, therefore, may adversely affect our business, results of operations, financial condition, the value of our securities and our ability to meet our financial obligations.

A sustained deterioration in the terms of trade given a decline in the global prices for Argentina’s main commodity exports or an increase in the global prices for Argentina’s main commodity imports, as well as adverse weather conditions affecting the production of Argentina’s main commodity exports, could have an adverse effect on Argentina’s economic growth.

High commodity prices have contributed significantly to an increase in Argentine exports, which has in turn led to an increase in government revenues received from export taxes. However, the reliance on the export of certain commodities, such as soybeans, has made the Argentine economy vulnerable to fluctuations in commodity prices, and, consequently, the Argentine economy could be adversely affected if trading conditions decline.

In addition, adverse weather conditions, such as floods or droughts, could affect the production of the main agricultural commodities produced by Argentina, which account for a significant portion of its export revenues. Moreover, higher oil prices could lead to an increase in government expenditures. The drought experienced during the summer months of 2018 dramatically reduced the yield from Argentina’s soybean crop. Most recently, after the outbreak of the COVID and the slowdown in the demand for supply of products around the globe, stock markets and the prices of the main commodities have declined dramatically.

Besides, in March 2020, after a failure to reach an agreement between the members of the Organization of the Petroleum Exporting Countries (“OPEC”) and Russia to stabilize the oil market, Saudi Arabia decided to increase its oil production. This decision, at a time when oil demand is falling due to the impact of COVID in the global trading and economy, has triggered the most important decline in the oil price since 1991, of around 30%. This fall in the international prices of oil and its derivatives added to the fragile macroeconomic situation in Argentina, generating uncertainty regarding the production and development of natural gas in the country, especially in the Vaca Muerta area. In December 2020, OPEC and its oil-producing allies agreed to increase production by 500,000 barrels per day beginning in January. The group exerts considerable influence over world energy markets.  In recent months, OPEC+ has sought to navigate its way through a historically tumultuous period, including an unparalleled collapse in oil prices, a massive fuel demand shock amid the COVID crisis, a Saudi-Russia price war and Qatar’s departure from OPEC. The downward trend in oil prices significantly reversed as a result of the invasion of Ukraine by Russia. Uncertainty about oil prices and other commodities remain and there can be no assurances about any measures that the Government may take in response to key macroeconomic variables, particularly on the energy sector.

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Decisions relating to international oil prices could have a negative impact on Argentina’s economy as, to achieve a fiscal surplus, the country should develop new production projects, such as Vaca Muerta formation, increase its revenues and maintain its ability to service its sovereign debt. Either of these results would adversely impact Argentina’s economic growth and, therefore, our financial condition and results of operations.

Further downgrades in the credit rating or rating outlook of Argentina could impact the rating of our securities or adversely affect the market price of our securities.

In August 2018, Moody’s revised its outlook of Argentina’s long-term and short-term sovereign credit rating to Caa2, primarily as a result of the sharply weaker economic activity and uncertain prospects for multiyear fiscal consolidation and market financing availability as IMF funds are used up, posing risks to sovereign debt sustainability. In addition, on August 29, 2019, S&P downgraded Argentina’s long-term and short-term sovereign credit ratings from “B” to “SD,” primarily as a result of an erosion of the Argentine debt profile, the economic growth trajectory and the dynamics of inflation, against the backdrop of the implementation of a challenging economic adjustment program. Fitch, Moody’s and S&P increased Argentina’s credit rating in September 2020 following the successful refinancing of Argentina’s external bonds. While the debt restructuring in 2020 improved Argentina’s credit rating, there are still concerns about debt sustainability and the country’s ability to meet its payment obligations in the future. In September 2021, Argentina’s credit rating according to Fitch Ratings was “RD” (restricted default) for foreign currency debt and “CC” for local currency debt. In March 2023, Fitch downgraded the credit rating to C, the lowest level above default.

However, there can be no assurance that Argentina’s credit rating or rating outlook will not be downgraded in the future, which could have an adverse effect on the rating of our securities or adversely affect the market price of our securities.

The Argentine government may mandate salary increases for private sector employees, which would increase our operating costs.

In the past, the Government has passed laws, regulations and decrees requiring companies in the private sector to maintain minimum wage levels and provide specified benefits to employees. Argentine employers, both in the public and private sectors, have experienced significant pressure from their employees and labor organizations to increase wages and to provide additional employee benefits. Due to high levels of inflation, employees and labor organizations regularly demand significant wage increases.

Through Decree No. 610/2019 a staggered increase of the minimum salary was approved as follows: (i) Ps.14,125 as of August 1, 2019; (ii) Ps.15,625 as of September 1, 2019; and (iii) Ps.16,875 as of October 1, 2019. In addition, the Argentine government has arranged various measures to mitigate the impact of inflation and exchange rate fluctuation in wages. In December 2019, Decree 34, doubled legally mandated severance pay for termination of employment. The Government went a step further amid the COVID pandemic, and issued Decree No. 329/2020, restricting the ability to terminate employment with or without cause for 60 business days, prorogued it for 60 additional business days by Decree No. 624/2020, finally it was extended until May 2021 by Decree N. 266/21. Also, in January 2020, the Argentine government issued Decree No. 14/2020 which established a general increase for all employees of Ps.3,000 in January 2020, and an additional amount of Ps.1,000 in February 2020 (total Ps.4,000 effective as of February 2020). The labor emergency was further extended by Decree No. 39/21 and Decree No. 886/21 through June 30, 2022. Decree 886/21 also provides that double severance payments will be progressively reduced until they were effectively finalized in June 2022.

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It is possible that the Argentine government could adopt measures mandating further salary increases or the provision of additional employee benefits in the future. Any such measures could have a material and adverse effect on our business, results of operations and financial condition.

Argentine corporations may be restricted from making payments in foreign currencies or from importing certain products

There are certain restrictions in Argentina that affect corporations ‘ability to access the MLC to acquire foreign currency to transfer funds to other countries, service debt, make payments outside Argentina and other operations, requiring, in some cases, prior approval by the Central Bank. These restrictions may affect our operations and our expansions projects, as they require the import of services and goods for which payment may be restricted. The Argentine Government may impose or create further restrictions on the access to the MLC. In such case, the ability of Argentine corporations to make payments outside Argentina and to comply with their obligations and duties may be affected.

In addition, as a result of the deepening of exchange controls, the difference between the official exchange rate, which is currently utilized for both commercial and financial operations, and other informal exchange rates that arose implicitly as a result of certain operations commonly carried out in the capital market, which increased during 2022, was a gap of approximately 94% as of December 31, 2022. The Argentine Government could maintain a single official exchange rate or create multiple exchange rates for different types of transactions, substantially modifying the applicable exchange rate at which we acquire currency to service our outstanding foreign currency denominated liabilities. We cannot predict how such current restrictions may evolve after this annual report, mainly regarding limitations to transfer funds outside the country.

The Argentine Government may impose further exchange controls or restrictions to capital transfers and modify and adopt other policies that may limit or restrict our ability to access international capital markets, to make payments of principal and interest and other additional amounts outside the country (including payments relating to our notes), to import certain products or goods that we use as inputs, or affect in other ways our business and our operational results, or cause the market value of our ADSs and our common shares to decline. Exchange controls in an economic environment in which the access to local capital markets is restricted may cause an adverse effect in our activities, mainly in our ability to make payments of principal and/or interest of our notes in foreign currency.

Argentina’s ability to obtain financing from international markets could be limited, which may impair its ability to implement reforms and foster economic growth and, consequently, affect our business, results of our operations and growth prospects.

Argentina’s history of defaults on its external debt and the protracted litigation with holdout creditors may reoccur in the future and prevent Argentine companies such as us from accessing the international capital markets readily or may result in higher costs and more onerous terms for such financing, and may therefore negatively affect our business, operational results, financial condition, the value of our securities, and our ability to meet our financial obligations.

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Following the default on its external debt in 2001, Argentina sought to restructure its outstanding debt in exchange offers in 2005 and again in 2010. Holders of approximately 93% of Argentina’s defaulted debt participated in the exchanges, but a number of bondholders held out from the exchange offers and pursued legal actions against Argentina. The Argentine Government settled several agreements with the defaulted bondholders, ending more than 15 years of litigation. In addition, in August 2020, the Argentine Government successfully negotiated the debt restructuring of Argentine bonds representing approximately US$65 billion owed to several bondholders.

On January 28, 2022, Argentina signed an agreement with the IMF to refinance more than US$40 billion in debt, contracted in 2018 with this institution. The main measures agreed are related to the reduction of public spending and subsidy rates, focused on the energy sector. The agreement was approved by the Argentinean Congress and by the Board of the IMF. Among other points, an economic and monetary policy was established, where the IMF will be the co-director, carrying out quarterly audits on Argentina’s finances and economic development.

Our company cannot predict how this new agreement and the policies developed based on it will impact Argentina’s ability to access international capital markets (and indirectly in our ability to access those markets) to access international capital markets, in the Argentine economy or in our economic and financial situation or in our capacity to extend the maturity dates of our debt or other conditions that could affect our results and operations or businesses.

The conflict between Russia and Ukraine could adversely affect the global economy, the Argentine economy and our operational results and financial condition.

On February 24, 2022, the President of Russia, Vladimir Putin, announced a military operation in the eastern Donbas region of Ukraine and began a full-scale invasion of the country.

The invasion received widespread international condemnation, with worldwide protests against the Russian invasion of Ukraine. The United States, the United Kingdom and other countries of the European Union imposed economic sanctions on Russia-such as the exclusion of certain Russian banks from the SWIFT financial system, airspace restrictions, export restrictions of Russian oil and gas, among others-which could eventually affect the supply of oil and gas from this country and trigger higher inflation and market shocks.

Actual and threatened responses to Russia’s invasion, as well as a rapid peaceful resolution to the conflict, may also impact the markets for certain commodities, such as electricity, oil and natural gas, and may have collateral impacts, including increased volatility, and cause disruptions to the availability of certain commodities, commodity and futures prices and the supply chain globally. Rising wheat prices raised tensions in countries like Egypt, which rely heavily on wheat exports from Russia and Ukraine, and sparked fears of social unrest. On the other hand, Russia is the second largest oil exporter in the world and the largest producer of natural gas, causing the world oil prices jumped over US$110 per barrel, and the cost of natural gas reached a new record high in Europe. In this sense, in Argentina, the natural gas supply for this next winter may be affected, with negative effects on the energy generation, especially for industries. The shortage on natural gas may adversely affect our pipeline system and operations.

We continue operating in a period of economic uncertainty and capital markets disruption, which has been significantly impacted by geopolitical instability since the ongoing military conflict between Russia and Ukraine, poor global economic performance, a potential recession looming in the U.S. and Europe and China showing weak growth.

Russia has increased attacks on Ukraine’s energy infrastructure. A settlement looks unlikely for now. Instead, we see an extended conflict, alongside a long-term political, economic, and military standoff between the West and Russia. The conflict in Ukraine has led to market disruptions, including significant volatility in commodity prices, credit and capital markets, as well as supply chain disruptions.

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Additionally, various of Russia’s actions have led to sanctions and other penalties being levied by the U.S., the European Union, and other countries, as well as other public and private actors and companies, against Russia and certain other geographic areas. See “—Risks Relating to Argentina — The conflict between Russia and Ukraine could adversely affect the global economy, the Argentine economy and our operational results and financial condition” for additional information.

The open conflict in Europe is a trigger for many the geopolitical risks over the short- and medium-term. As Western sanctions on Russia bite and Russia weaponizes energy, the siege-like standoff between the West and Russia may escalate, and ripple effects from Ukraine war will continue to amplify challenges as emerging markets face a slow rebound from COVID, including high food and energy costs, higher U.S. interest rates, a strong U.S. dollar and slow Chinese growth.

Any of the above-mentioned factors could affect our business, prospects, financial condition, and operating results. The extent and duration of the military action, sanctions, and resulting market disruptions are impossible to predict, but could be substantial. Any such disruptions may also magnify the impact of other risks described in this Annual Report.

Risks Relating to Our Shares and ADSs

Shareholders outside Argentina may face additional investment risk from currency exchange rate fluctuations in connection with their holding of our shares or ADSs represented by ADRs. Exchange controls imposed by the Government may limit our ability to make payments to the Depositary in U.S. dollars, and thereby limit ADR holders’ ability to receive cash dividends in U.S. dollars.

We are an Argentine company and any future payments of dividends on our shares will be denominated in pesos. The peso has historically fluctuated significantly against many major world currencies, including the U.S. dollar. A depreciation of the peso would likely adversely affect the U.S. dollar or other currency equivalent amount of any dividends paid on our shares and could result in a decline in the value of our shares and ADRs as measured in U.S. dollars.

From 2011 to December 2015, Argentine companies were required to obtain prior approval from BCRA and Argentine tax authorities in order to engage in certain foreign exchange transactions. In September 2019 the Government reinstalled the above previous measures and since then has implemented additional exchange control restrictions. Thus, our shareholders’ ability to receive cash dividends in U.S. dollars was limited by the ability of the Depositary for our ADR program to convert cash dividends paid in pesos into U.S. dollars. Under the terms of our Deposit Agreement for the ADRs, to the extent that the Depositary can in its judgment, and in accordance with local exchange regulations, convert pesos (or any other foreign currency) into U.S. dollars on a reasonable basis and transfer the resulting U.S. dollars outside of Argentina, the Depositary will as promptly as practicable convert or cause to be converted all cash dividends received by it in pesos on the deposited securities into U.S. dollars. If in the judgment of the Depositary this conversion is not possible on a reasonable basis (or is not permitted by applicable Argentine laws, regulations and approval requirements), the Depositary may distribute the pesos received or in its discretion hold such currency uninvested without liability for interest thereon for the respective accounts of the owners entitled to receive the same. As a result, if the exchange rate fluctuates significantly during a time when the depositary cannot convert the foreign currency, you may lose some of the value of the dividend distribution.

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In the event that the BCRA does not grant the applicable authorization, we reserve the right to agree with the Depositary the reasonable legal measures for the effective payment of dividends to ADR holders who reside outside of Argentina. As a result, such ADR holder may not timely receive the full dividend distribution or receive at all any such distribution.

Our principal shareholders exercise significant control over matters affecting us, and may have interests that differ from those of our other shareholders.

As of the date of this Annual Report, our controlling shareholder is CIESA, which holds 51% of our common stock. FGS holds 24.0% of our common stock. Local and foreign investors hold the remaining ownership of our common stock. CIESA is under co-control of Pampa Energía S.A. (“Pampa Energía”), which holds 50% of CIESA’s common stock, and Grupo Inversor Petroquímica S.L. (member of GIP Group, controlled by the Sielecki family; “GIP”), and PCT L.L.C. (“PCT”), which directly and indirectly through PEPCA S.A. (“PEPCA”) holds a 50% of the common stock of CIESA.

We cannot assure you that the interests of our principal shareholders will not diverge from the interests of our other investors. See “Item 7. Major Shareholders and Related Party Transactions.”

Sales of a substantial number of shares could decrease the market prices of our shares and the ADRs.

CIESA holds 51% of our Class “A” shares. Pursuant to the Pliego de Bases y Condiciones para la Privatización de Gas del Estado S.E. (the “Pliego”), CIESA may not reduce its shareholding below 51% of our share capital without the competent authorities’ approval. The market prices of our common shares and ADRs could decline as a result of sales by our existing shareholders, such as the ANSES, or of any other significant shareholder of common shares or ADRs in the market, or the perception that these sales could occur.

Under Argentine law, shareholder rights may be fewer or less well defined than in other jurisdictions.

Our corporate affairs are governed by our Bylaws, the General Companies Act and Law No. 26,831, which differ from the legal principles that would apply if we were incorporated in a jurisdiction in the United States or in other jurisdictions outside Argentina. In addition, rules governing the Argentine securities markets are different and may be subject to different enforcement in Argentina than in other jurisdictions.

As a foreign private issuer we are exempt from certain rules that apply to domestic U.S. issuers.

We are subject to the informational requirements of the Exchange Act applicable to foreign private issuers. Under U.S. securities laws, as a foreign private issuer we are exempt from certain rules that apply to domestic U.S. issuers with equity securities registered under the Exchange Act.

For example, as a foreign private issuer, in the United States, we are not subject to the same disclosure requirements as a domestic U.S. registrant under the Exchange Act, including the requirements to prepare and issue quarterly reports on Form 10-Q or to file current reports on Form 8-K upon the occurrence of specified significant events, the proxy rules applicable to domestic U.S. registrants under Section 14 of the Exchange Act or the insider reporting and short-swing profit rules applicable to domestic U.S. registrants under Section 16 of the Exchange Act. In addition, we have relied, and intend to keep relying, on exemptions from certain U.S. rules which permit us to follow Argentinian legal requirements rather than certain of the requirements that are applicable to U.S. domestic registrants. As a result of the above, even though we are required to file reports on Form 6-K disclosing the information which we have made or are required to make public pursuant to Argentinian law, or are required to distribute to shareholders generally, and that is material to us, you may not receive information of the same type or amount that is required to be disclosed to shareholders of a U.S. company

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We are also exempt from many of the corporate governance requirements of the New York Stock Exchange.

Changes in Argentine tax laws may adversely affect the tax treatment of our Class B Shares or ADSs.

Pursuant to Law No. 26,893, the sale, exchange or other transfer of shares and other securities is subject to capital gains tax at a rate of 15% when the purchaser and the seller are not Argentine residents. When both the purchaser and the seller of our Class B Shares or ADRs are non-residents, the purchaser is required to pay the capital gains tax in addition to the purchase price of the Class B Shares or ADSs. In addition, if the purchaser is legally liable for capital gains taxes in Argentina, then the purchaser will likely not be entitled to receive any tax credit in the United States in respect of the payment of any such taxes.

On December 29, 2017, the Macri Administration enacted, through Decree No. 1112/2017, a tax reform (the “Tax Reform”). The Tax Reform provides that only the results from sales, transfers or dispositions of shares, securities representing shares and certificates of deposit of shares that are carried out through stock exchanges or stock markets authorized by the CNV under conditions that guarantee the principle of price/time priority of the offers obtained by individuals and undivided estates resident in Argentina shall be exempted.

The foregoing exemption shall also be applicable to foreign beneficiaries to the extent that said beneficiaries do not reside in and the funds do not come from non-cooperative jurisdictions. Decree No. 279/2018 provides that until the decree of the Income Tax Law of Argentina regulates the definition of non-cooperative jurisdiction, the white-list established in Decree No. 589/2013 (dated 05/27/2013) will be applicable to determine if a jurisdiction is non-cooperative jurisdiction.

The Tax Reform also establishes an exemption for such foreign beneficiaries on the sale of share certificates issued outside of Argentina that represent shares issued by Argentine companies which have been granted with a public offering authorization by the CNV (i.e., ADRs). The exemptions will only apply if the foreign beneficiaries do not reside in and the funds do not arise from “non-cooperating” jurisdictions.

Pursuant to Decree No. 279/2018, if the foreign beneficiary resides in a non-cooperative jurisdiction or the funds come from a non-cooperative jurisdiction, the capital gains tax rate is 35%.

Whereas, previously, if the sale was carried out between non-Argentine residents the non-Argentine resident purchaser was responsible for paying the tax when the seller was a non-resident, currently it is the seller, through their legal representative domiciled in Argentina, who is responsible for paying the tax, except when the purchaser is a resident individual or legal entity. If the seller does not have a legal representative, the tax should be paid by the seller according to Decree No. 279/2018.

Further rulemaking or interpretation of the amended income tax law by the Argentine tax authority may adversely affect the tax treatment of our Class B Shares or ADSs.

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Holders of ADRs may be unable to exercise voting rights with respect to our Class B Shares underlying the ADRs at our shareholders’ meetings.

We will treat the Depositary for all purposes as the shareholder with respect to the shares underlying the ADRs. As a holder of ADRs representing the ADRs being held by the Depositary in your name, you will not have direct shareholder rights and may exercise voting rights with respect to our Class B Shares represented by the ADRs only in accordance with the Deposit Agreement. There are no provisions under Argentine law or under our Bylaws that limit the exercise by ADR holders of their voting rights through the Depositary with respect to the underlying Class B Shares. However, there are practical limitations on the ability of ADR holders to exercise their voting rights due to the additional procedural steps involved in communicating with these holders. ADR holders may be unable to exercise voting rights with respect to our Class B Shares underlying the ADRs as a result of these practical limitations.

Holders of ADRs may be unable to exercise preemptive, accretion or other rights with respect to the Class B shares underlying the ADSs.

Holders of ADSs may not be able to exercise the preemptive or accretion rights relating to the shares underlying the ADSs unless a registration statement under the Securities Act is effective with respect to those rights or an exemption from the registration requirements of the Securities Act is available. We are not obligated to file a registration statement with respect to the shares relating to these preemptive rights, and we cannot assure you that we will file any such registration statement. Unless we file a registration statement or an exemption from registration is available, holders may receive only the net proceeds from the sale of their preemptive rights by the depositary or, if the preemptive rights cannot be sold, they will be allowed to lapse. As a result, U.S. holders of Class B Shares or ADSs may suffer dilution of their interest in our company upon future capital increases.

In addition, under the General Companies Act, foreign companies that own shares in an Argentine corporation are required to register with the Superintendency of Corporations (Inspección General de Justicia or the “IGJ”) in order to exercise certain shareholder rights. Voting rights in a Shareholder meeting can be exercised through duly instituted agents, as is regulated by Law No. 26,831. If you own our Class B Shares directly (rather than in the form of ADSs) and you are a non-Argentine company and you fail to register with the IGJ, your ability to exercise your rights as a holder of our Class B Shares may be limited.

The NYSE and/or BYMA may suspend trading and/or delist our ADSs and common shares, respectively, upon occurrence of certain events relating to our financial situation.

The NYSE and/or the BYMA may suspend and/or cancel the listing of our ADSs and common shares, respectively, in certain circumstances, including upon the occurrence of certain events relating to our financial situation.

The NYSE may in its sole discretion determine on an individual basis the suitability for continued listing of an issue in the light of all pertinent facts. Some of the factors mentioned in the NYSE Listed Company Manual, which may subject a company to suspension and delisting procedures, include: “unsatisfactory financial conditions and/or operating results,” “inability to meet current debt obligations or to adequately finance operations,” and “any other event or condition which may exist or occur that makes further dealings or listing of the securities on the NYSE inadvisable or unwarranted in the opinion of NYSE.”

We cannot assure you that the NYSE and/or BYMA will not commence any suspension or delisting procedures. A delisting or suspension of trading of our ADSs or common shares by the NYSE and/or BYMA, respectively, could adversely affect our results of operations and financial conditions and cause the market value of our ADSs and common shares to decline.

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The price of our Class B Shares and the ADSs may fluctuate substantially, and your investment may decline in value.

The trading price of our Class B Shares is likely to be highly volatile and may be subject to wide fluctuations in response to factors, many of which are beyond our control. Such factors include:

• fluctuations in our periodic operating results;

• changes in financial estimates, recommendations or projections by securities analysts;

• changes in conditions or trends in our industry;

• events affecting equities markets in Argentina;

• legal or regulatory measures affecting our financial conditions;

• departures of management and key personnel; or

• potential litigation or the adverse resolution of pending litigation against us or our subsidiaries.

The stock markets in general have experienced extreme price and volume fluctuations that have often been unrelated or disproportionate to the operating performance of the companies involved. We cannot assure you that trading prices and valuations will be sustained. These broad market and industry factors may materially adversely affect the market price of our Class B Shares and the ADSs, regardless of our operating performance. Market fluctuations, as well as general political and economic conditions in Argentina, such as recession or currency exchange rate fluctuations, may also adversely affect the market price of our Class B Shares and the ADSs. In particular, currency fluctuations could impact the value of an investment in Argentina. Although our ADSs listed on the NYSE are U.S. dollar-denominated securities, they do not eliminate the currency risk associated with an investment in an Argentine company.

For example, due to various factors (including, but not limited to, the abrupt variation in the exchange rate in Argentina) prices of equity securities in Argentina have decreased substantially since 2018, which prompted investors to dispose of their investments in Argentina resulting in further downward pressure on the price of equity securities. Future sales of substantial amounts of our Class B Shares and ADSs, or the perception that such future sales may occur, may result in additional pressure on the price of our Class B Shares and ADSs. Also, future sales of treasury shares, may also have a negative impact on the price of our Class B Shares and ADSs.

Following periods of volatility in the market price of a company’s securities, that company may often be subject to securities class-action litigation. This kind of litigation may result in substantial costs and a diversion of management’s attention and resources, which would have a material adverse effect on our business, results of operations and financial condition.

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The relative volatility and illiquidity of the Argentine securities markets may substantially limit the ability to sell the Class B Shares underlying the ADSs on the BYMA at the price and time desired by the shareholder.

Investing in securities that trade in emerging markets, such as Argentina, often involves greater risk than investing in securities of issuers in the United States, and such investments are generally considered to be more speculative in nature. The Argentine securities market is substantially smaller, less liquid and more concentrated and can be more volatile than major securities markets in the United States and is not as highly regulated or supervised as some of these other markets. There is also significantly greater concentration in the Argentine securities market than in major securities markets in the United States Accordingly, although shareholders are entitled to withdraw the Class B Shares underlying the ADSs from the depositary at any time, the ability to sell such shares on the BYMA at a price and time shareholders might want may be substantially limited.

Item 4. Our Information

A. Our History and Development

General

Operations

We commenced commercial operations on December 28, 1992, as the largest company created in connection with the privatization of Gas del Estado S.E. (“GdE”), the Argentine state-owned natural gas company, the integrated operations of which included natural gas transportation and distribution. GdE was divided into ten companies: two transportation companies and eight distribution companies.

Our legal name is Transportadora de Gas del Sur S.A. We are a limited liability company (sociedad anónima), incorporated under the laws of Argentina on December 1, 1992. Our registered offices are located at Don Bosco 3672, 5th Floor, Buenos Aires (C1206ABF), Argentina, our telephone number is (54 11) 4865-9050 and our web address is www.tgs.com.ar. According with our public records, our length of life is set to expire on November 30, 2091 (which could be renewed, in accordance to the applicable law).

We are currently the largest transporter of natural gas in Argentina and operate the most extensive pipeline system in Latin America in terms of length, delivering approximately, as of December 31, 2022, 60% of the total natural gas transported in Argentina, through 5,736 miles of pipeline, of which we operate 4,775 miles on an exclusive basis pursuant to the License (the “Natural Gas Transportation”). Our transportation system connects the Neuquén, San Jorge and Austral basins, the major natural gas fields located in the south and west of Argentina, to the greater Buenos Aires area and the major consumption centers of southern Argentina. During the Fiscal Year 2022, approximately 83% of our revenues of this business segment corresponds to firm natural gas transportation services under firm long-term natural gas transportation contracts. Natural gas transportation customers with firm contracts pay for the contracted pipeline capacity regardless of actual usage. Our Natural Gas Transportation business is regulated by ENARGAS, and revenues from this business represented 25%, 28% and 42% of our total revenues for the years ended December 31, 2022, 2021 and 2020, respectively.

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We conduct our Natural Gas Transportation business pursuant to the License, which is currently scheduled to expire in 2027 and which is extendable for an additional ten-year period at our option if certain technical conditions described in the License are met. ENARGAS is required at that time to evaluate our performance and make a recommendation to the Executive Branch for the extension of our License. If ENARGAS determines that we are in substantial compliance with all our obligations arising under the Natural Gas Law No. 24,076 (the “Natural Gas Law”), related regulations and our License, the extension should be granted by the Executive Branch. ENARGAS would bear the burden of proving that we had not met the technical conditions referred to above and, therefore, that the extension of the License should not be granted. To the extent that we were found not to have satisfied the conditions described above or chose not to seek the extension of our License, we would be entitled to certain specified compensation. See “—B. Business Overview—Natural Gas Transportation—Regulatory Framework—Certain Restrictions with Respect to Essential Assets” below.

The License gives us the exclusive right to operate the existing southern Argentine natural gas transportation pipeline system. Our natural gas transportation system connects major natural gas fields in southern and western Argentina with both distributors and large consumers of natural gas in those regions as well as in the greater Buenos Aires area, the principal population center of Argentina.

The map below illustrates the natural gas pipeline system in Argentina as of December 31, 2022:

 

For additional information regarding our property, plant and equipment, see “D. Property, Plant and Equipment” below.

We are also one of the largest processors of natural gas and one of the largest marketers of Liquids in Argentina. We operate the Cerri Complex and the associated logistics and storage facilities of Puerto Galván located in Bahía Blanca in the Province of Buenos Aires where Liquids are separated from the natural gas transported through our pipeline system and stored for delivery. Due to its strategic location within the Argentine natural gas transportation system, our Cerri Complex can process gas proceeding from the Neuquén, San Jorge and Austral basins. This provides the plant with great versatility in terms of natural gas availability, and the possibility to select the gas that is processed according to its quality (liquid contents). Revenues from our Liquids Production and Commercialization business represented 64%, 63% and 49% of our total revenues during the years ended December 31, 2022, 2021 and 2020, respectively.

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We also provide midstream integral solutions related to natural gas production, from the wellhead up to the transportation systems. In addition, through our subsidiary Telcosur, we provide telecommunications services. Aggregate net revenues from our midstream and telecommunications business segment represented 12%, 10% and 9% of our total revenues during the years ended December 31, 2022, 2021 and 2020, respectively.

Within the framework of the agreements signed with the former Ministry of Energy, Mining and Hydrocarbons of the Province of Neuquén and Gas y Petróleo de Neuquén S.A. in April and November 2018, we timely completed the construction of a catchment and gathering pipeline and a natural gas conditioning plant in the Vaca Muerta field that will allow the gathering of non-conventional gas from the Neuquina basin and its subsequent injection into the main gas pipeline systems, ensuring its supply to all of Argentina’s regions.

The Vaca Muerta system has two gathering pipes: the first has a length of 71 miles, a 36” diameter and a 35 MMm3/d transportation capacity (the “Northern Section”) and the second has a 22 miles extension, a 30” diameter and 25 MMm3/d transportation capacity (the “Southern Section”). The gas transported through this pipeline system is treated at a new conditioning plant that we built at Tratayén, Province of Neuquén with an initial capacity of 7.8 MMm3/d. This project consolidates our position as the first midstream services provider in the Vaca Muerta field and required an investment of approximately US$260 million in the aggregate. On April 29, 2019, the assembly and pressurization works on the connection of the Vaca Muerta pipeline to Neuba II Gas Pipeline were completed, which led to revenues from the month of May 2019 derived from firm natural gas transportation contracts of 28.2 MMcf/d in the aggregate. On August 22, 2019, the SHR issued Resolution No. 491/2019, which declared this project as “critical” pursuant to Law No. 26,360. This allows us to obtain certain tax benefits from the investments in this project.

On March 2022, tgs executed an agreed minute with the Undersecretary of Energy, Mining and Hydrocarbons of the Province of Neuquén (Subsecretaría de Energía, Minería e Hidrocarburos de la Provincia del Neuquén) (the “Complementary Agreed Minute”) whereby the parties commit to granting us an extension of the transportation concession to build and operate the pipeline expanded North Tranche II, which will gather the off-spec natural gas production from several hydrocarbons fields located mainly in the Vaca Muerta formation (the “Expanded North Tranche II”). In August 2022, we began this work with an investment of approximately US$ 60 million, this 20 miles long work will extend from the Los Toldos I Sur area to El Trapial (Vaca Muerta Norte). The pipeline is expected to be commissioned in June 2023.

For more information regarding our investments in Vaca Muerta area see “Item 4. Our Information—B. Business Overview—Other Services—Midstream Services.”

Controlling shareholders

As of the date of this Annual Report, our controlling shareholder is CIESA, which holds 51% of our common stock. Other local and foreign investors hold the remaining shares of our common stock, including FGS, which holds 24% of our common stock. CIESA is under co-control of Pampa Energía which holds 50% of the common stock of CIESA, and GIP and PCT, which directly and indirectly through PEPCA hold 50% of the common stock of CIESA.

For additional information regarding CIESA’s current organizational structure, see “Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders.”

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Capital expenditures

From January 1, 2020, through December 31, 2022, our aggregate capital expenditures, in Current Currency, amounted to Ps. 61,946 million. Such capital expenditures include Ps. 32,311 million related to improvements to our gas transportation system, Ps. 9,484 million related to liquids production and commercialization activities and Ps. 20,151 million related to Other Services segment.

For the years 2022, 2021 and 2020, capital expenditures mostly include improvement to our gas transportation system and works performed for the construction and ramping-up of the Northern Section and Southern Section of the Vaca Muerta pipeline and the enhancement of Tratayén Plant and maintenance works of our natural gas pipeline system. Information relating to the size and financing of future investments is included in “Item 5. Operating and Financial Review and Prospects”.

Available documentation

The SEC maintains an Internet site that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC and state the address of that site (http:// www.sec.gov). Our internet address is www.tgs.com.ar. This URL is intended to be an inactive textual reference only. It is not intended to be an active hyperlink to our website. The information included in our website or which may be accessed through our website is not part of this Annual Report, is not incorporated by reference herein or otherwise and should not be relied upon in determining whether to make an investment in any securities issued by us.

B. Business Overview

NATURAL GAS TRANSPORTATION

As a transporter of natural gas, we receive natural gas owned by a shipper, usually a natural gas distributor, at one or more intake points on our pipeline system for transportation and delivery to the shipper at specified delivery points along the pipeline system. Under applicable law and our License, we are not permitted to buy or sell natural gas except for our own consumption and to operate the pipeline system. See “—Regulatory Framework” below for more information.

Our pipeline system connects major natural gas fields in southern and western Argentina with distributors and other users of gas in those areas and the greater Buenos Aires area. TGN, the only other natural gas transportation operating company that supplies the Argentine market, holds a similar license with respect to the northern pipeline system, which also provides natural gas transportation services to the greater Buenos Aires area.

Natural gas transportation services accounted for 25%, 28% and 42% of our total revenues in the years ended December 31, 2022, 2021 and 2020, respectively. In 2022, 77% of our average daily natural gas deliveries were made under long-term firm transportation contracts. See “—Customers and Marketing” below. Natural gas firm transportation contracts are those under which capacity is reserved and paid for regardless of actual usage by the customer. Almost all of our natural gas firm contracted capacity is currently subscribed for at the maximum tariffs allowed by ENARGAS. During 2022, the amount of net revenues derived from natural gas firm transportation contracts was Ps. 33,984 million, representing 83% of the total revenues for the Natural Gas Transportation segment for such year. Substantially all of our remaining natural gas deliveries were made under natural gas interruptible transportation contracts entered into predominantly with four natural gas distribution companies, power plants and industrial customers. Interruptible contracts provide for the transportation of natural gas subject to available pipeline capacity. The Government has at times directed us to interrupt supply to certain customers and make deliveries to others without regard as to whether they have natural gas firm or interruptible contracts. See “Regulatory Framework—Industry Structure” below for more information.

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Expansions of the system. In February 2017, the Ministry of Mines and Energy called for a national public tender for the purchase of pipelines to extend the natural gas network in some areas of the Province of Santa Fé, the Patagonian Andes and the coast of the Province of Buenos Aires.

Within this framework, we entered into a Transitional Union Agreement (“UT”) with SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A. (“SACDE”), a related company, for the purpose of participating jointly in the National Public Bid No. 452-0004-LPU17: Assembly of Pipes for the Construction of the Project “Expansion of the Natural Gas Transportation and Distribution System.” In this regard, the Ministry of Mines and Energy awarded to the aforementioned UT the construction of the Regional II-Recreo/Rafaela/Sunchales Regional Gas Pipeline.

As a result of the economic context and COVID, the UT sent a letter to Integración Energética Argentina S.A. (“IEASA” formerly ENARSA), a company that is currently part of the Ministry of Productive Development, requesting, among other issues, the reestablishment of the economic-financial equation, readjustment of the work schedule, approval of cost redeterminations and price adjustments under the legal regime in force.

On July 9, 2021, the UT and IEASA signed a restarting order and a restarting act of the works related to the Sunchales pipeline (the “Sunchales Work”), by means of which the work schedule was readjusted and IEASA also assumed the commitment to manage and join efforts to guarantee the cash flow in order to avoid new impacts to the economic-financial structure of the contract of the Work, which would give rise to new requests - on the part of the UT - for the recomposition of the economic-financial equation of the contract and of the execution schedule of the Sunchales Work.

As of the date of this Annual Report, the interim price adjustments mentioned in the preceding paragraph are pending payment; this situation notoriously affected the normal development of the project and the fulfillment of the term foreseen in the respective agreement.

On September 5, 2018, through Resolution No. 125/2018 of the former Ministry of Energy, such Ministry resolved to discontinue the execution of works under the “Northern Work Trust 2006-2008” and the “Southern Work Trust 2006-2008,” formed on December 6, 2006, under the regime of Decree No. 180/2004 of February 13, 2004 and Resolution No. 185/2004 of April 19, 2004, of the former MPFIPyS. Likewise, such resolution instructed Nación Fideicomiso (“NAFISA”) and TGN, as trustees, respectively, of the “Northern Work Trust 2006-2008” and of the “Ampliación Norte 2004-2005 Trust” to consolidate the assets of both, in the “Northern Work Trust 2006-2008,” to continue with the repayment of the contributions and pending investments, without prejudice to the rights of third parties. Also, such resolution instructed NAFISA and us, as trustees, respectively of the “Trust of South Work 2006-2008” and the “Trust Expansion South 2004-2005” to consolidate the assets of both in the “South Work Trust 2006-2008,” which will continue with the repayment of contributions and pending investments, without prejudice to the rights of third parties. Furthermore, the resolution entrusts NAFISA to carry out the residual projects of the “Northern Work Trust 2006-2008” and of the “Southern Work Trust 2006-2008” and to carry out the timely liquidation of the “Ampliación Norte 2004-2005 Trust” and the “Fideicomiso Ampliación Sur 2004-2005,” giving the former Ministry of Energy the appropriate authority in accordance with the provisions of Decree No. 180/2004 and Resolution No. 185/2004.

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On February 7, 2022, the Secretary of Energy issued Resolution No. 67/2022 creating the “Transport.Ar Producción Nacional” Gas Pipeline System Program (the “Transport.Ar Program”) and declaring the construction of the NK Pipeline and complementary works as of public interest. The total investment will be roughly US$3.4 billion, of which 75% are expected to be allocated to the construction of the pipeline.

Once online, it will save on imports of natural gas, LNG and liquid fuels, at least US$1b/year. Moreover, the country will be able to export more, especially to the bordering countries.

This is a 35-year concession granted to IEASA. It can designate a third-party to build, operate and maintain the facility.

Also, by means of Decree No. 76/2022 dated February 11, 2022, the concession of this gas pipeline was granted to IEASA for a term of 35 years and the trust FONDESGAS (Fondo de Desarrollo Gasífero Argentino) was created, with IEASA as trustee and beneficiary, and BICE (Banco de Inversión y Comercio Exterior, a public bank) as trustee.

The construction of the NK Pipeline is vital importance for the Argentine energy development. The construction of the NK Pipeline is set to occur in two different stages:

• the first stage began at the end of 2022. It will connect the town of Tratayén in the Province of Neuquén with the town of Salliqueló in the Province of Buenos Aires, where it will be connected to the gas pipeline system operated by us. The initial capacity of the NK Pipeline of 11 MMm3/d is expected to be online by winter 2023. Finally by mid of 2024 after the construction of compressor plants the total capacity of this stage will be 21MMm3/d.

• The second stage will connect to San Jerónimo area un the Province of Buenos Aires and the south of the Province of Santa Fé. The total capacity will be 39 MMm3/d with a length of 746 miles.

The works will be carried out by IEASA, which will be able to do it by directly or indirectly, with priority to YPF. In the event that for the execution of the works the Secretary of Energy opens a call for bids, we will evaluate the convenience of participating in the provision of the operation and maintenance service.

Customers and Marketing

Our principal service area is the greater Buenos Aires region in central-eastern Argentina. We also serve the more rural provinces of western and southern Argentina. As of December 31, 2022, our service area contains 6.3 million end users, including 4.1 million customers in the greater Buenos Aires area. Direct service to residential, commercial, industrial and electric power generation end users is mostly provided by four gas distribution companies in the area, all of which are connected to our pipeline system: Metrogas S.A., Naturgy Argentina S.A., Camuzzi Gas Pampeana S.A. and Camuzzi Gas del Sur S.A. These natural gas distribution companies serve, in the aggregate, 65% of the natural gas distribution market in Argentina. The other five Argentine distribution companies are located in and serve northern Argentina and are not connected directly to our pipeline system.

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The table below contains certain information for the year ended December 31, 2022, as it relates to the distribution companies that are connected to our pipeline system:

Company	Annual deliveries (MMm3)		Volume of market served (in %)			No. of end users (in millions)		Deliveries received from us (in %)
Metrogas (1)		6.0		19.6			2.4		71
Camuzzi Pampeana (1)		5.7		18.6			1.4		94
Camuzzi Sur		4.6		15.0			0.8		100
Naturgy Argentina (1)		3.7		12.1			1.7		66
				65.4	%		6.3

(1) Also connected to the TGN system.

Source: ENARGAS

The firm average contracted capacity for our four largest distribution customers, Pampa Energía and for all other customers, as a group, as of December 31, 2022, 2021 and 2020, together with the corresponding net revenues derived from natural gas firm transportation services during such years and the net revenues derived from interruptible services during such years are set forth below:

	For the years ended December 31,
	2022				2021				2020
	Average firm contracted capacity (MM3/d)		Net revenues (millions of pesos)		Average firm contracted capacity (MM3/d)		Net revenues (millions of pesos)		Average firm contracted capacity (MM3/d)		Net revenues (millions of pesos)
Firm:
Metrogas		16.7		10,356		16.7		11,822		16.7		17,317
Camuzzi Pampeana		15.8		7,669		15.8		8,709		15.8		12,660
Naturgy Argentina		11.8		6,286		11.8		7,051		11.8		10,320
Camuzzi Sur		11.0		1,817		11.2		2,013		11.0		2,595
Pampa Energía		3.2		1,471		4.0		1,667		4.3		2,630
Others		24.5		6,386		23.3		7,545		22.9		10,597
Total firm		83.0		33,984		82.6		38,806		82.5		56,118
Interruptible and others:				6,659		-		8,924		-		12,983
Total		83.0		40,463		82.6		47,730		82.5		69,101

We play a leading role in the natural gas industry in Argentina and satisfy 70 direct customers and 6.3 million indirect customers for the year ended December 31, 2022.

As of December 31, 2022, the total contracted firm or “ship or pay” capacity was 83.1 MMm3/d with a weighted average life of approximately 11 years.

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Pipeline Operations

Pipeline Deliveries. The following table sets forth our average daily natural gas firm and interruptible transportation deliveries for 2022, 2021 and 2020:

	For the year ended December 31,
	2022			2021			2020
Firm:	Average daily deliveries (MMm3/d)			Average daily deliveries (MMm3/d)			Average daily deliveries (MMm3/d)
Metrogas		12.9			11.7			12.1
Camuzzi Pampeana		10.8			10.4			9.3
Camuzzi Sur		7.1			7.3			6.8
Naturgy Argentina		6.7			6.4			6.1
Others		15.6			15.8			15.4
Subtotal firm		53.1			51.6			49.7
Subtotal interruptible		15.5			16.7			14.5
Total		68.6			68.3			64.2
Average annual load factor (1)		83	%		83	%		78	%
Average winter heating season load factor (1)		85	%		95	%		86	%

(1) Average daily deliveries for the period divided by average daily firm contracted capacity for the period, expressed as a percentage.

Natural gas daily average injection to the pipeline system operated by us amounted to 68.6 MMm3/d in 2022, 2% higher than the 69.7 MMm3/d of 2021. It should be noted that the contribution of the Neuquén basin was 13% higher than last year, while the southern basin decreased its injection by 11%.

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The chart below shows the main operating data for the natural gas transportation segment.

Natural Gas Transportation System Improvements. In 2022, 2021 and 2020, we made capital expenditures aimed at the enhancement of our natural gas transportation system’s safety and reliability in the aggregate amount of Ps.8,566 million. We operate our pipeline system and the pipeline constructed pursuant to the Gas Trust in accordance with Argentine natural gas transmission safety regulations, which are substantially similar to U.S. federal regulations. Based on the pipeline inspection reports we have received to date and the current operation of the pipeline system, we do not foresee any significant safety risks. In order to identify changes in the safety regulations that our pipeline system has to comply with, we conduct inspections for the purpose of detecting increases in the population density in the areas through which our pipeline system extends. Changes in population densities may require us to increase safety measures in certain sections of the system.

The “greater” Buenos Aires area comprises the City of Buenos Aires and its surrounding area. One end of our natural gas transportation system (the “Buenos Aires Ring”) is located in the greater Buenos Aires area, where we transfer natural gas for further delivery to major natural gas distribution companies.

Actions Taken During the COVID Emergency. Especially during 2022, to guarantee the reliability of the transportation system and the safety and health of our workforce and customers during the COVID emergency, a reliability strategy was implemented, focusing on critical maintenance tasks for the system, supported by planning process, training and raising hygiene awareness and implemented protocols to prevent the spreading of the COVID, which allowed us to achieve compliance with the plans on time, without major incidents and overcoming emerging obstacles.

We considered technical, logistical, operational and occupational safety and health prevention aspects in the operation and maintenance activities have allowed us to:

• protect the health and safety of operating personnel;

• ensure operational continuity in the event of contagion of key personnel;

• ensure the proper functioning of equipment and facilities;

• guarantee the quality of services to internal and external clients;

• identify additional actions to be taken during and after an emergency; and

• maintain fluid communication and monitoring of personnel and their condition.

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Likewise, and within the framework of this emergency, we optimized capital investments and operating expenses, without affecting the safety and reliability tasks that allow us to operate the gas pipeline system in accordance with current regulations.

System Improvements. In 2022, 2021 and 2020, our pipeline system satisfactorily met the demands generated by the winter season and the requirements of ENARGAS. To that effect, we carried out several maintenances, prevention and inspection works.

During 2022, we conducted integrity assessment tasks, such as in-line inspections along 1,246 miles of pipelines and direct assessment through CIS+DCVG techniques (sections with no Scraper Traps) over 286 miles of pipelines. The purpose of these tasks is to identify, assess and control threats to pipelines integrity - such as external corrosion, geometrical defects, manufacture and/or construction anomalies, recoating failures, among others.

In line with our 2022 recoating program, we changed recoating over 8 miles of the pipeline system. This pipeline rehabilitation program has been the most significant of this kind ever undertaken by tgs, not only because of its economic scope but also due to the technical deployment it has entailed.

While performing the works mentioned in the foregoing paragraph we also conducted non –destructive tests by means of the use of magnetic particles, ultrasound and hardness measurements for the identification of anomalies in longitudinal weld seams, stress corrosion cracking (“SCC”) and Hard-Spot, by means of which we were able to detect anomalies that could be mitigated through pipe replacements. The purpose of these recoating works is to mitigate the risk of external corrosion and SCC as well as to survey and mitigate any pipe anomaly that in the future may deteriorate the ducts and interrupt the service. Thus is how we extend the useful life of our facilities.

We also conducted Recoating Works at the Scraper Trap launcher and receiver facilities of Salamanca.

To mitigate corrosive activity we carried out filling works in reinforcement sleeves to ensure integrity in high population density areas.

We launched an inline inspection plan with “EMAT” technology to detect cracks colonies, within the framework of the SCC assessment and mitigation plan. In the year 2022, we inspected 226 miles in the Neuba I Pipeline. As a result of the inline inspection with ultrasonic crack detection (UTCD) in liquid cavity we carried out at the discharge of the San Julian compressor plant, we could optimize the analysis of the EMAT inspections conducted previously, which led to the reprocessing of 20 inline inspection reports by the contractor, enhancing SCC cracking detection capacity.

On the other hand, seeking to ensure that inline inspection processes conducted at we meet best practices and international standards and always on the lookout for opportunities for improvement, in 2022 we conducted an audit to the inline inspection company that works with us, focusing on their staff competences and overall service quality.

There is no doubt that this innovating approach and synergy between tgs and the contractor improve the service efficiency on the whole and guarantee our pipelines condition for the service.

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Departing from an analysis and planning conducted by the pipeline integrity team, we conducted an assessment campaign of 170 external corrosion and geometrical defects, anomalies in longitudinal and circumferential seams, which required immediate repairs that were executed by means of the installation of 13 reinforcement sleeves and 15 pipe replacements.

Within the scope of cathodic protection, to mitigate the advance of corrosion and improve reliability, we kept strengthening the system with the installation of 3 new units and 13 current reinforcement lenses as well as the renewal of 15 facilities that were obsolete.

We continued works to mitigate third party damage risks in the high population density segment of the Buenos Aires Ring. We expanded the optical fiber intruder detection system, between the cities of San Vicente and Berazategui. This work complements the one conducted last year, totaling an aggregate coverage of 67 miles of pipeline monitored via intruder detection systems. Besides, we have intensified the signaling of our facilities all along the pipeline system in highly populated areas, among other measures. Additionally, on the most sensitive sections of the system, we conducted virtual and remote damage prevention activities, such as communications via radio, media and networks for the public in general, meetings with municipalities and ground-breaking & services companies in Buenos Aires, Neuquén and Rio Negro. Also, we conducted door-to-door communication campaigns in Neuquén, Rio Negro and Bahía Blanca in the communities near the pipeline, with the aim of raising awareness regarding gas pipelines’ related risks and how to prevent them.

Concerned with the safety of our people, we concluded works to adapt the grounding of 25 Cathodic Protection units, thus reducing the risk of electric shock at our facilities.

We assessed the integrity of 12 derivations located in the Las Heras – Pacheco pipeline section. This work allows us to check the overall condition of the facility and conduct the adjustments required to ensure service continuity.

We successfully completed the 2022 winter maintenance program, which allows us to guarantee a safe and reliable operation of the pipeline system.

We carried out works at the compressor plants located in Moy Aike and Magallanes to make the system operation more flexible and prevent the stoppage of turbine compressors, extending their operation hours.

We also installed scraper trap launchers and receivers for maintenance and cleaning purposes in certain sections of pipeline and we also used Smart Pigs to detect each section’s integrity status. This activity was carried out in the province of Buenos Aires, in loops to the Neuba II main gas pipeline and in the General Cerri – Las Heras section. We also installed trap launchers in the San Martin Pipeline in the cities of de Cerro Redondo and Magallanes.

The construction of a new fuel gas regulation skid at the Olavarría compressor plant allowed us to separate the operation of each turbine, improving the individual performance of each unit.

We updated the fire and gas systems at the turbine machine housing of the Bosque Petrificado plant, upgrading the system to a NFPA standard (National Fire Protection Association). The system’s trigger is reported to the plant control room and through SADYC –data and control acquisition system – to the Cerri node. Besides, we added a blocking and venting system to the fuel gas line in the event that the system is triggered.

In addition, we improved facilities at the Confluencia Compressor Plant in terms of operative safety.

To ensure operations continuity at the Magallanes plant, we worked to decouple discharges to make outflows independent so if there is damage in the main or loop pipeline, the plant may remain in service.

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Transportation measurement methods were improved as well, with the installation of clamps on measurement systems, directly on the pipelines, rather than at the compressor plant. These works were conducted at the Magallanes, Dolavon and Manantiales Behr compressor plants. We also conducted improvements at measurement stations located in the Buenos Aires Ring in Las Heras, Ezeiza and Gutiérrez.

Works at Liquids Facilities

We carried out works aimed at extending the useful life of pressure containers and ducts’ to boost reliability and reduce risks at facilities. These tasks comprised several unit inspections and preventive maintenance at our facilities, including the Galvan Plant poliducts.

To improve the reliability of the Cryogenic Train C, inspections were performed in the critical processing units, increasing their useful lives. We also replaced the exchanger D2-317C, ensuring the energetic exploitation of the process, replacing dehydration exit filters, increasing the process current flow and updating the turbine expander C’s instruments and control.

A significant landmark in our operations —started in 2020—was the finalization of the GE turbine machinery replacement and the assembling of the new pressurization system in the casing of said turbine machinery. This year, focused on operative efficiency and continuity at our facilities, we completed the assembling of vapor compressor at the Environment Plant and we replaced the start systems of the cryogenic plants’ cooling circuits, increasing the reliability of the ambient-temperature and cooled hydrocarbons storage and dispatch. On the other hand we started ongoing investments to mitigate technological obsolescence risk and increase our processes operative safety: air compressor for quality certifications chromatograph, new battery bank to increase the reliability of the safe energy system of the Absorption Plant and the Cerri Complex compressor plants, new electrical engines to boost the reliability of absorption and transfer processes from Cerri to Galván, implementation of the SIS in vapor generator heaters and fire central at the Cerri storage.

It is worth mentioning the new fire-fighting network for the Cryogenic Plant electricity distribution transformers and for the propylene and gasoline tanks at the Galván plant.

We conducted the major maintenance of 24,000 hours of the MC White 1B, and the 16,000 hours maintenance of the MC White 2A, critical equipment of the cooling circuit and the deethanizer process of the Absorption Plant.

Focused on the continuous and safe management of facilities, we certified and adapted the relief systems of the 12 Langmar tanks in line with Resolution Secretary of Energy 404/94. On the other hand gasoline tank 1 was enabled in accordance with Res. Secretary of Energy 785/2005. Further tasks related to regulations included the implementation of emergency lighting at the Cryogenic Train C. With respect to enhancements to meter systems, a new level meter was installed at the gasoline tank 2 and three touch screens were assembled at the truck loading area, completing the updating of the allocation project for the six loading isles.

Improvement works at the Río Neuquén treatment and compression plant consisted mainly in the change of pipes in the cooling towers. We also conducted several tasks in the pipe systems that will ensure greater reliability in the rendering of related services.

We also enlarged the Control Room to improve working conditions, extending the surface to meet staff and equipment space needs. We also installed new fire systems to improve the safety of our facilities, protecting both our assets and our staff.

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At the Rio Neuquén plant we are conducting works to enhance reliability and service continuity, focusing on operative safety and environment, safety and government aspects (“ESG”).

Works at Vaca Muerta facilities

We continued with the Tratayén plant expansion process, which is developed in line with requirements to increase Midstream services supply. Expansion works this year included the installation of two conditioning units with Joule Thompson technology that increase the conditioning capacity by 7 MMm3/day and two other conditioning modules of Propak turbine expanders that in the future can be converted to the processing of gathered natural gas, which will increase the conditioning capacity by 6.6 MMm3/day, each of them. It is foreseen that future investments will target the installation of additional identical modules.

Focused on the growth of the Vaca Muerta system, in 2023 we are starting the works required to add auxiliary services such as a new gasoline stabilization plant (the third for this facility) as well as the purchase of new land.

Moreover, as mentioned above, we are completing the expansion of the Northern Vaca Muerta pipeline from Los Toldos to the Trapial field with a 20 miles length and a nominal diameter of 30 inches.

We also conducted works for third parties, putting into service several facilities such as the Vista and Tecpetrol links to the VM pipeline system.

Technical Assistance Services Agreement. As part of its bid to purchase a 70% interest in us from the Government, CIESA was required to have an investor-company with experience in natural gas transmission that would serve as our technical operator. In late 1992, we entered into a Technical Assistance Agreement with PEPCA (the “Technical Assistance Agreement”), an indirect, majority-owned subsidiary of Enron Corp. (“Enron”). The term of the Technical Assistance Agreement was for eight years from December 28, 1992, renewable automatically upon expiration for an additional eight-year term and was assigned to Petrobras Argentina S.A. (“Petrobras Argentina”) as part of a master settlement agreement. Since July 2004, Petrobras Argentina was our technical operator and was in charge of providing assistance related to, among others, the operation and maintenance of the natural gas transportation system and related facilities and equipment in order to ensure that the performance of the system is in conformity with international natural gas transportation industry standards and in compliance with certain Argentine environmental standards.

On July 27, 2016, Petrobras Argentina was acquired by Pampa Energía. For further information, see “Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders.”

With the prior approval of ENARGAS and our Board of Directors, in December 2017, we and Pampa Energía agreed to a technical, financial and operational assistance service agreement (the “SATFO”) for a three-year term. The SATFO substantially contains the same terms as the Technical Assistance Agreement, as amended. However, the scope of the contract was extended to include a greater number of services that Pampa Energía must render us. Any amendment, assignment or even termination of the SATFO has to be authorized by ENARGAS. Pursuant to the SATFO, the currency for the technical assistance fee paid to Pampa Energía is U.S. dollars. Our Audit Committee analyzed the SATFO and concluded that its price is on market terms.

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The SATFO sets out the services to be provided by Pampa Energía to us, at the request of our Chief Executive Officer. Between December 2017 and October 2019, we received from Pampa Energía technical, financial and operational assistance and we paid a monthly fee for such services in amounts equal to the greater of (i) US$3 million and (ii) an amount equal to 7% of the difference between our net income before interests and income taxes of the most recently ended twelve-month period and US$3 million.

The services provided by Pampa Energía to us under the SATFO include assisting us in the following matters to the extent that they arise in the ordinary course of business: (i) replacement, repair and renovation of facilities and equipment to ensure that the performance of the system is in accordance with international gas transportation industry standards; (ii) preparation of performance evaluations, operating cost analysis, construction assessments and advice related to budget control; (iii) advice regarding safety, reliability and efficiency of system operation and gas industry services; (iv) advice regarding compliance with applicable laws and regulations relating to safety and industrial hygiene, pollution and environmental protection of the system; (v) routine and preventive maintenance of the system; (vi) staff training; (vii) design and implementation of the necessary procedures to provide with the aforementioned services; (viii) financial and insurance advice; (ix) advice on operational improvements such as risk analysis, generation and commercialization of electric energy, operative management of the “midstream,” human resources management, and legal and supply management; (x) advice on non-regulated businesses such as midstream, electric, petrochemical, processing, and construction, among others; and (xi) design and implementation of all major aspects of natural gas transportation and liquids production, as well as administrative information and control system to adequately inform our management group.

Our Board of Directors, at its meeting held on September 17, 2019, approved a proposal for Pampa Energía, as technical operator of the SATFO, for a significant reduction in the compensation it receives under the SATFO. The general and special shareholders meeting held on October 17, 2019, ratified such proposal. The Audit Committee also expressed its favorable opinion to such proposal, as required by the Capital Markets Law, because Pampa Energía is our related party.

According to such amendment, we extended the term of the SATFO until December 27, 2024 (automatically renewable for three more years) and replaced the provisions relating to the calculation of the fee payable to Pampa Energía. Pursuant to the amended SATFO, the monthly fee payable to Pampa Energía shall be equal to the greater of: (i) US$0.5 million and (ii) an amount equal to the percentage specified below for the corresponding period applied to the difference between our net income before interests and income taxes of the most recently ended twelve-month period:

• From 12/28/2019 to 12/27/2020: 6.5%

• From 12/28/2020 to 12/27/2021: 6%

• From 12/28/2021 to 12/27/2022: 5.5%

• From 12/28/2022 to 12/27/2023: 5%

• From 12/28/2023 to 12/27/2024 and onwards: 4.5%.

For the year ended December 31, 2022, we recorded a charge of Ps.3,067 million for services rendered by Pampa Energía pursuant to the amended SATFO.

The Argentine Natural Gas Industry

Historical Background. Prior to the privatization of GdE, the Argentine natural gas industry was effectively controlled by the Government.

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In 1992, the Natural Gas Law was passed providing for the privatization of GdE. The Natural Gas Law and the related decrees provided for, among other things, the transfer of substantially all of the assets of GdE to two natural gas transportation companies and eight distribution companies. Currently there are nine authorized companies to distribute natural gas in Argentina. The ninth concession was added in 1998 and covers the Mesopotamian provinces, Formosa, Chaco, Entre Rios and Misiones which previously had no network for natural gas service. The license for the Mesopotamian region was awarded to GasNea S.A. The transportation assets were divided into two systems on a broadly geographical basis, the northern and southern trunk pipeline systems, designed to give both systems access to natural gas sources and to main centers of demand, including the greater Buenos Aires area. As a result of the division, our natural gas transportation system is connected to the two natural gas distribution systems serving the greater Buenos Aires area, one serving Buenos Aires Province (excluding the greater Buenos Aires area and the northeast of this province) and one serving southern Argentina. TGN is connected to five distribution systems serving northern Argentina. TGN is also connected to the natural gas distribution systems serving the greater Buenos Aires area and, to a limited extent, the natural gas distribution system serving Buenos Aires Province (excluding the greater Buenos Aires area). In the two instances where we are directly connected to a natural gas distribution system with TGN, we are the principal supplier of natural gas transportation services.

The Natural Gas Law and the related decrees granted each privatized natural gas transportation company a license to operate the transferred assets, established a regulatory framework for the privatized industry based on open, non-discriminatory access, and created ENARGAS to regulate the transportation, distribution, marketing and storage of natural gas. The Natural Gas Law also provided for the regulation of wellhead gas prices in Argentina for an interim period. Prior to deregulation, the regulated price was set at US$0.97 per million British thermal units (“MMBtu”) at the wellhead, which had been the regulated price since 1991. Pursuant to Presidential Decree No. 2,731/93, gas prices at the wellhead were deregulated as of January 1, 1994 and, from that date until the year 2002, the average price of gas increased.

In spite of the devaluation of the peso in 2002, increases in wellhead natural gas prices were limited until 2004. From May 2004 until August 2005, wellhead gas prices increased in a range from 105% to 180% (depending on the gas basins) for power plants, industries and large businesses. These adjustments were complemented by lower increases in the price of natural gas for CNG vehicles.

In October 2008, the former Federal Energy Bureau through Resolution No. 1,070/2008 increased natural gas at the wellhead for residential, CNG and power station users. According to this resolution, natural gas producers agreed to transfer all of the increase in prices actually received less certain deductible amounts to a trust fund established by Law No. 26,020, to allow low-income consumers with no access to natural gas to buy LPG at a subsidized price (the “Stabilization Agreement”). With Resolution No. 73/2015, the Federal Energy Bureau, under Decree No. 470/2015, ordered the termination of the trust approved by Resolution No. 1,080/2008 with effect from April 1, 2015. Through the Stabilization Agreement, we agreed to supply LPG fractionation companies at a reference price, which is substantially below market prices, certain volumes of LPG, which are determined by the SHR. As compensation, we received a fixed fee determined by the SHR.

In recent years, the Argentine natural gas industry has experienced rising demand, decreased supply, and lower investment in exploration, production, transportation and distribution of natural gas as a result of economic factors, including the economic recovery of many industries and GDP growth, and government restrictions on increases in the wellhead price of natural gas and in the transportation and distribution tariffs.

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As a result of this environment, the Government implemented a set of measures designed to address the combination of rising demand and lower investment in exploration, production, transportation and distribution of natural gas, including, among others:

• creation of IEASA (formerly ENARSA) in 2004 for the purposes of restoring levels of reserves, production and supply of natural gas and meeting the infrastructure needs of the natural gas transportation and electricity industries;

• hiring of two re-gasifying LGN tankers through IEASA, in Bahía Blanca (2008) and Escobar (2011), to inject natural gas into the pipeline. The tanker located at Bahía Blanca, which was retired in November 2018, was connected to our pipeline, and the tanker at Escobar is connected to TGN’s pipeline;

• establishment of a framework for the constitution of Gas Trusts to finance natural gas pipeline expansions works in transportation and distribution of natural gas;

• the passage of Law No. 26,741, which declares that hydrocarbons self-sufficiency, as well as their production, industrialization, transport and marketing, are activities of public interest and primary goals of Argentina, empowering the Government to take the necessary measures to achieve such goals;

• importation of natural gas from Bolivia and Chile, which has increased significantly over the past two years;

• creation of tariff charges to be paid by all consumers other than residential consumers in order to finance natural gas and electricity expansions and the import of natural gas;

• In order to foster the production of natural gas, the Argentine government adopted different programs, including the “Natural Gas Additional Injection Stimulus Program”, Gas Plan II (implemented by means of Resolution No. 60/2013), and the “Stimulus Program for New Natural Gas Projects” (Programa de Estímulo a los Nuevos Proyectos de Gas Natural);

• the establishment of the 2020-2024 natural gas scheme through the Gas.Ar Plan; and

• the establishment of the Transport.Ar Program which declares of public interest the building of the NK Pipeline in order to solve the natural gas transportation bottleneck from the Neuquén Province.

On December 23, 2019, the Government enacted Solidarity Law, declaring a public emergency in economic, financial, fiscal, administrative, pension, tariff, energy, health and social matters. The Solidarity Law establishes that (i) natural gas tariffs under federal jurisdiction will remain unaltered for a term of one hundred eighty (180) days as from December 23, 2019, and (ii) the executive branch is empowered to renegotiate tariffs under federal jurisdiction, either within the framework of the current general tariff reviews or through an extraordinary review, in accordance with Law No. 24,076 (Gas Law).

On June 19, 2020, Decree No. 543/2020 extended the 180-day term established in Article 5 of the Social Solidarity Law until the end of 2020. On December 17, 2020, Decree No. 1,020 / 2020 extended the freezing of electricity and natural gas rates for a period of 90 days or until the new transitory rate schedules agreed in the transitory agreements come into effect. Also, the Solidarity Law entitles the Argentine Executive Branch to intervene in the management of the ENARGAS. Afterwards, the intervention was extended until December 31, 2022, by means of Decree No. 871/2021.

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On December 6, 2022, by means of Decree No. 815/2022, the term for the completion of the RTI established in Decree 1020 was extended for a period of 1 year as from its expiration, i.e. until December 18, 2023. It also extends, as from January 1, 2023, the intervention of ENARGAS, which is instructed, while the renegotiation continues, to carry out the necessary measures in order to achieve a transitional tariff adjustment, in accordance with Decree 1020.

In January 2017, the Government announced the implementation of certain benefits in order to increase oil and natural gas production. This announcement was aimed at attracting local and foreign investments with an emphasis in the Vaca Muerta formation of the Neuquina basin. The announcements included:

• an agreement with unions to amend current existing collective bargaining agreements for the sector;

• the elimination of the obligation of repatriation of funds due to oil and gas exports currently regulated by Decree No. 1,722/11; and

• the creation of a program (regulated by Resolution No. 46-E/2017), the Investment in Natural Gas Production from Non-Conventional Reservoirs Stimulus Program, which establishes a support price for the volume of non-conventional natural gas production from concessions located in the Neuquina basin included in the program. This program, originally scheduled to be effective until December 31, 2021, included a sliding-scale schedule for the minimum price to be paid per MMBtu: US$7.50 for 2018, US$7.00 for 2019, US$6.50 for 2020 and US$6.00 for 2021. In 2019, such program was modified by the Energy Secretary, and such decision of the Government resulted in conflicts between the Government and natural gas producers which led to a sharp decline in the number of investments made by natural gas producers since the second half of 2019.

Since March 2020 and during the rest of such year, the oil and NGL prices fell sharply and were very volatile primarily due to the COVID pandemic and geopolitical tensions among OPEC members and Russia. In addition, the quarantine measures taken by the Government to slow down COVID spread have caused a significant decrease in the consumption of natural gas and gasoline. The demand for natural gas in the industrial sector was affected by a reduction of small industries that were paralyzed especially in the Great Buenos Aires, and some large industries that have reduced their activity.

Additionally, the domestic demand for fuels decreased considerably due to the contraction in consumption. Likewise, important restrictions were verified by the main exporting companies as a consequence of the restrictions imposed by the different countries for the unloading of products.

By means of Decree No. 892/2020, dated November 13, 2020, the Government implemented the Gas.Ar Plan. The purpose of such plan is to encourage investments in natural gas exploration and production through the implementation of prices and incentives. The plan also implements a direct contracting mechanism between (i) natural gas producers and distributors and sub-distributors (to satisfy priority demand) and (ii) CAMMESA. Such contracting will be made taking the PIST as a reference, a tender procedure carried out by the SE.

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According to the Gas.Ar Plan, the Argentine government may assume on a monthly basis payment of a portion of the price of natural gas in the PIST, in order to mitigate the impact of the cost of natural gas to be transferred to end users. The BCRA established mechanisms to guarantee the repatriation of direct investments and their respective returns and/or the payment of principal and interest of foreign financings, provided that such funds have been entered into to Argentina through the Argentine Foreign Exchange Market as from the entry into force of the decree and are used to finance projects under the Gas.Ar Plan.

The Secretary of Energy is tasked with implementing the plan. The Secretary is assigned the power to implement a plan with maximum volume, terms and price references for natural gas, applicable to supply agreements between suppliers and demanding agents to be executed within the framework of the plan, and that ensure the free formation and transparency of prices in accordance with Law No. 24.076.

On December 3, 2020 the first auction was held within the framework of the Gas.Ar Plan by means of which the government promoted to have a base of 70 MMm3/d, corresponding to the Neuquina basin 47.2 MMm3/d, to the Austral Basin 20 MMm3/d and to the Northeast Basin 2.8 MMm3/d, plus additional volumes in winter. Producers in the Neuquén Basin offered 49.35 MMm3/d. From the Austral Basin, bids totaled 18.5 MMm3/d. In other words, in total, the initiative achieved a commitment of 67.85 MMm3/d, just below the target.

On February 22, 2021, pursuant to Resolution No. 129/2021, the Secretary of Energy called for a new bidding within the framework of the Gas.Ar Plan to supply with domestic natural gas production the highest demands of the winter period. Companies submitted their bids for a volume of up to 4.5 MMm3. The weighted price of round two for the winter of 2021 was 4.731 US$/MMbtu. For the winters of 2022, 2023 and 2024 the volume bid was 3.36 MMm3/day at a weighted average price of 4.73 US$/MMbtu.

In mid-October 2021 the third round of the Plan Gas.Ar was called through Res. 984/21. In it, the purchase of 3 million m3/day of gas from the Neuquina basin, 1.5 million m3/day from the South of the country and 1 million m3/day from the Northwest was tendered for the years 2022 to 2024 inclusive, with injection starting next winter 2022.

There were only offers from the Neuquina basin. The natural gas production of the Neuquina basin represented approximately 60% of the total production of natural gas in Argentina during 2021.

Through Res. No. 770/2022, on November 11, 2022, the Secretary of Energy called for an auction for the extension of the commitments assumed by the awardees in the Neuquina Basin in Rounds 1 and 3, as well as the award of the following incremental volumes in the Neuquina Basin. At the same time, through the above mentioned resolution the Secretary of Energy also called for an auction for:

1) The extension of the commitments assumed by those awarded in the provinces of Chubut and Santa Cruz within the framework of the procedures carried out in Round I (Round 5.1).

2) The presentation of Incremental Gas projects in the Austral and Northwest basins, under the figure of Incremental Activity Plan according to the definition of Decree No. 892/2020, replaced by Decree No. 730/2022, with the purpose of obtaining additional volumes of natural gas to reinforce the injections of the transportation system in those points where there is available capacity (Round 5.2).

Under this round, an incremental gas project was received from CGC to increase production in the Austral basin, in its Santa Cruz and Santa Cruz Norte areas (San Jorge Gulf) with a net contribution to the system of more than 2 MMm3/d for next winter and of approximately 2.60 MMm3/d for 2024 at an average price of US$ 7.40 per MMBTU.

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The companies that were awarded in Rounds 4 and 5 of the Gas Ar Plan were: YPF, Shell, Pampa Energía, PAE, CGC, Pluspetrol, Tecpetrol, Total, Exxon Mobil, Petrobras, Vista and Wintershall Dea. It is important to highlight that bid were received for more than 45 MMm3/d for the filling of the President Néstor Kirchner Gas Pipeline, more than double the capacity expected to be available in early 2024. In addition, offers were obtained to cover the winter peak at a price close to US$ 5/MMBTU.

As the economic activity recovered in 2021, the oil and NGL prices have also started to increase. In addition, the invasion of Ukraine by Russia significantly increased oil prices which continue to be very volatile.

On October 29, 2021, the Secretary of Energy issued Resolution No. 1,036/2021 establishing the guidelines for an energy transition plan 2030. This plan contemplates a series of measures aimed at reducing CO2 emissions, efficient energy consumption and a plan for the promotion of gasification actions in the country, which contemplates making the necessary investments to bring gas to the points of consumption.

On February 9, 2022, through Resolution 67 the Government created the Transport.Ar Program which intends to solve the infrastructure deficit. Resolution 67:

• Declares the construction of the NK Pipeline to be of National Public Interest as a strategic project for the development of natural gas in the Argentine Republic (which will transport natural gas starting from the Province of Neuquén, crossing the Provinces of Río Negro, La Pampa, Buenos Aires, up to the Province of Santa Fe), as well as its complementary works, and the construction of the works for the expansion and strengthening of the National Natural Gas Transportation System.

• Creates the Transport.Ar Producción Nacional with the purpose of promote de development and growth of natural gas production and supply, optimizing the transportation system, increasing natural gas exports, promoting regional integration, among others.

• The Secretary of Energy shall conduct this program, in order to guarantee the development of natural gas in the market, in accordance with the objectives set forth in Resolution 67/2022 and with the provisions of Decree No. 892/2020 (Gas.Ar Plan) and Resolution No. 1. 036/2021 of the Secretary of Energy.

Also, through Decree No. 76/2022 of February 11, 2022, the concession of this gas pipeline was granted to IEASA for a term of 35 years and the trust FONDESGAS (Fondo de Desarrollo Gasífero Argentino) was created, with IEASA as trustee and beneficiary, and Banco de Inversión y Comercio Exterior (“BICE”) as trustee.

The construction of the President Néstor Kirchner Gas Pipeline and its complementary works is of vital importance for the Argentine energy development and will imply both fiscal benefits and foreign currency savings for Argentina.

Natural Gas Demand. Natural gas consumption in Argentina has played a significant role in the energy industry in recent years, reaching more than 50% of total national energy consumption, which is greater than the comparable percentage for worldwide energy consumption. The graphic below illustrate the breakdown of natural gas consumption in Argentina in 2021 and 2022 by type of consumer:

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Source: ENARGAS

Beginning in 2003, a sharp increase in natural gas demand occurred as a consequence of: (i) the recovery of certain industries in the Argentine economy in 2003, (ii) the 2002 devaluation of the peso as well as the transportation and distribution tariffs and the elimination of both tariff and wellhead gas price adjustments, making this fuel relatively inexpensive for consumers as compared to other types of fuel, the prices of which are affected by inflation, (iii) the growth of GDP between 2003 and 2013 and (iv) the energy policy that seeks to be one of the main producers of natural gas that allows not only to replace the import of natural gas but also to generate the necessary resources for its export. As a result, natural gas became, by far, the cheapest fuel in Argentina and high rates of substitution of natural gas for other fuels in industry, power plants and vehicles have been observed. Likewise, the rising demand for gas has also been based on the recovery of many industrial segments of the Argentine economy, and the lack of availability of natural gas to meet current demand represents a challenge for continued industrial growth at the rates achieved in recent years.

The demand for natural gas in Argentina is highly seasonal, with natural gas consumption peaks in winter. The source of seasonal changes in demand is primarily residential consumers. In order to bridge the gap between supply and demand, especially with respect to peak-day winter demand, the Government has entered into several natural gas import agreements.

The most important agreement was signed with the Bolivian government in June 2006 and amended in May 2010 and July 2012. The agreement provides for the import of natural gas from Bolivia to Argentina to be managed by IEASA to deal with the decrease in domestic natural gas production and in an effort to maintain supplies at similar levels to the previous years. During 2022, the sixth addendum to the Bolivian import contract came into force, which modifies the price formula and, due to the decline in Bolivian fields, reduces supply volumes. The seventh addendum to the gas import contract between Energía Argentina (Enarsa) and YPFB (Yacimientos Petrolíferos Fiscales Bolivianos) was signed on December 30, 2022 and includes a reduction in the volume of natural gas that will be received.

Natural gas consumption during 2022 was 137 MMm3/d, registering a 2.1% increase in natural gas consumption compared to the previous year (+3 MMm3/d), mainly driven by higher consumption of priority demand as a result of lower temperatures and higher exports due to greater availability of natural gas. The increase could have been even higher if it were not for the impact of the Russia-Ukraine war on the price of LNG and the consequent drop in imports through the regasification terminals of Escobar and Bahía Blanca. The electricity sector cushioned this impact by substituting part of the natural gas consumption with substitute fuels (gasoil, fuel oil, coal).

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During the second quarter of 2022, average temperatures were colder (13.9°C) than those recorded in the same period of 2021 (15.3°C), which explains the increase in priority demand (residential + SMEs) with respect to the previous year, registering an average increase of 2.5 MMm3/d.

Due to the incentive scheme proposed by the Gas.Ar Plan, production levels were increased and this trend will continue throughout 2022. This greater availability of local natural gas led to a sustained increase in exports, mainly to Chile through the Gas Andes pipeline, even during the winter months, taking advantage of the fact that the shipment of such volumes would not restrict supply in the domestic market given the current design of the transportation infrastructure.

Despite a 3.6% increase in electricity demand, total electricity generation decreased by 2.2% (-3.0 TWh), the difference being covered by imports mainly from Brazil. The drop in local generation is mainly explained by lower thermal generation (-7.7 TWh) due to the economic need to minimize fuel imports (liquids and LNG) and, to a lesser extent, by lower nuclear generation (-2.7 TWh) due to lower availability at its three plants. The lower thermal and nuclear generation was partly offset by a recovery of hydroelectric generation (+25.2%; + 6.1 TWh) compared to 2021, although river contributions remained at levels below the historical average. In turn, renewable energies continue to grow (+10.9% vs. 2021) contributing 14% of total generation (19.3 TWh) to the system.

The following graph shows the monthly consumption in 2022 in MMm3/d for each of the demand sectors, compared to the total demand in 2021 (in red line).

Gas Supply. There are 24 known sedimentary basins in the country, 12 of which are located entirely onshore, six of which are combined onshore/offshore and eight of which are entirely offshore. Production is concentrated in five basins: Norwest in northern Argentina, Neuquén and Cuyo in central Argentina, and Golfo San Jorge and Austral in southern Argentina. In 2022, 60% of the natural gas transported by our system originated in the Neuquina basin with the remainder coming primarily from the Austral basin and the re-gasifying LGN tanker located in Bahía Blanca. Our pipeline system is connected to the Neuquina, Austral and San Jorge Gulf basin. We are not connected to the Cuyo or Northwest basin.

The graph below shows the evolution of gross natural gas production by basin from 2012 to 2022 in MMm3/d:

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Source: Secretary of Energy

Set forth in the table below is the location of the principal natural gas producing basins by province, their proved natural gas reserves, reserve life and production as of December 31, 2021 and 2020 (the most recent years for which information is available):

Basin	Location by province	Proved Gas Reserves (MMm3)(1)(2)				Production (MMm3)				Reserve Life (years)(3)
		2021		2020		2022		2021		2021
Neuquina	Neuquén, Río Negro, La Pampa, Mendoza (South)		268.5		244.9		33.0		28.9		9
Austral	Tierra del Fuego, Santa Cruz (South), and offshore		78.8		86.2		9.9		10.9		7
San Jorge Gulf	Chubut, Santa Cruz (North)		36.3		35.4		4.1		3.9		9
Cuyo	Mendoza (North)		0.2		0.2		0.0		0.0		3
Northwest	Salta, Jujuy, Formosa		8.1		9.4		1.4		1.5		5
Total			391.9		376.1		48.4		45.3		7

(1) Estimated as of December 31, 2021 and 2020, respectively. There are numerous uncertainties inherent in estimating quantities of proved natural gas reserves. The accuracy of any reserve estimate is a function of the quality of available data, and engineering and geological interpretation and judgment. Results of drilling, testing and production after the date of the estimate may require substantial upward or downward revisions. Accordingly, the reserve estimates could be materially different from the quantity of natural gas that ultimately will be recovered.

(2) Reserve figures do not include significant reserves located in certain Bolivian basins to which TGN is connected.

(3) Weighted average reserve life for all basins, at the 2021 production levels, respectively.

Source: Secretary of Energy.

Given the marked seasonality of natural gas demand in Argentina, with consumption peaks in the winter months, where the residential sector is mainly the source of such fluctuations in demand, Argentina’s domestic natural gas production together with the natural gas import contract from Bolivia satisfies consumption during the warmer months (October through April), but production is insufficient to meet demand needs during the colder months (May to September), requiring Argentina to import additional volumes of natural gas from pipelines interconnecting it with neighboring countries (mainly Bolivia and occasionally Chile) and imports through LGN regasification vessels. However, during the first part of 2021 and despite the higher import volumes from Bolivia, liquid fuel consumption was needed to meet the natural gas demand of power plants given the drop in natural gas production and the lack of water availability in hydroelectric power plants.

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In 2022, total natural gas production increased 6.8% over the previous year, from 124.1 MMm3/d to 132.6 MMm3/d.

In 2022, YPF continued to be the main producer in Argentina with a 28% market share, followed by Total Austral S.A. with a 23% market share. The graph below shows the market share of the main natural gas operators in Argentina in terms of production for 2022.

Main Natural Gas Producers 2022

Source: Secretary of Energy

The supply from Bolivia -under the agreement signed between both governments- resulted in an average of 10.4 MMm3/d, 2.6 MMm3/d less than the volume recorded in 2021. On the other hand, LNG imports by sea, re-gasified and injected into the national natural gas transportation system at the port of Escobar and Bahía Blanca located in the Province of Buenos Aires, recorded an average contribution of 6.2 MMm3/d in 2021, 3.4 MMm3/d below the LNG contribution recorded in 2021.

Total natural gas injection in the month of June 2022, the highest level for the year, was 129 MMm3/d, an additional 13 MMm3/d over the June 2021 record.

The Neuquina basin has the largest total natural gas injection, while the remaining basins continue with their natural decline (even Bolivia is also in the process of decline), which made the construction of a third trunk pipeline imperative to evacuate the incremental gas associated with the development of reserves in the Neuquina basin.

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The Vaca Muerta formation, located in the Neuquina Basin, is considered one of the most prominent shale plays globally, and has already become the largest commercial shale development outside of North America. The development of the Vaca Muerta formation plays an important role in the Argentine economy, and therefore the national and provincial governments have introduced changes to the regulatory framework for exploration and production of unconventional hydrocarbons, in order to attract investments.

Our strategy aims at being a protagonist in Argentina’s energy development. In fact, in 2018, with a vision of the future, tgs anticipated what the country required: it took a risk and built the Vaca Muerta System, consisting of 93 miles of gas pipelines and a gas treatment plant in Tratayén to allow entry into the regulated transportation systems.

Distribution of the Vaca Muerta Formation in the Basin and our infrastructure

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Source: Internal information

Vaca Muerta is in a relatively early stage of its development compared to shale plays in the United States and Canada. The Permian Basin is a good analogue for Vaca Muerta, with similar geological characteristics and a long history of unconventional hydrocarbon development.

According to the Argentina gas and power market outlook of June 2022, prepared by the consulting firm Wood Mackenzie, the Neuquina Basin, hand in hand with Vaca Muerta, has a really significant development potential. The development scenarios depend on the assumptions considered in relation to the production stimulus programs such as the Gas Plan.Ar, as well as the existence of demand and projected transportation infrastructure. Based on these scenarios, the natural gas production projection for the Neuquina Basin by 2040 could reach levels in the order of 150 million cubic meters per day for the base case or in the order of 200 million cubic meters per day for the higher development case, which assumes a faster development of transportation infrastructure (pipelines) and access to export markets.

Neuquina Basin. The largest natural gas basin and the major source of natural gas supply for our system is the Neuquina basin, located in west central Argentina. Since the discovery of Vaca Muerta formation, this basin is the most prolific basins of the country accounting 68% of natural gas production in the country.

Since then, the development of non-conventional gas in the Province of Neuquén has played a leading role in the increase in production of natural gas.

After the implementation of Gas.Ar Plan, production in the Neuquina basin during 2022 was 14% higher than the previous year. This is a variation above the average and made it possible to compensate for the drop in production in the remaining basins.

Natural gas production in Vaca Muerta increased 41.2% during the last twelve from November 30, 2021 to November 30, 2022. Vaca Muerta represents 37% of the total gas produced in the country in 2022. In this case the three main operators are Tecpetrol, which is the main operator, YPF and Total Austral. In the Vaca Muerta formation Tecpetrol increased its annual production 24.5%, YPF’s production was 51% higher and Total Austral increased its annual production by 34.2.%.

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The TGN system also accesses the Neuquina basin. Of the transported natural gas coming from the Neuquina basin, approximately 61% was transported by us and approximately 39% by TGN for the year ended December 31, 2022.

Undoubtedly, the biggest challenge in this Basin, given the potential of Vaca Muerta, is to develop the appropriate infrastructure for the transportation of natural gas. In this sense, in 2018 we have carried forward the construction of the Vaca Muerta Norte and Sur gas pipeline and the Tratayén conditioning plant with its subsequent expansions. In this sense, the beginning of the NK pipeline works is particularly important. For additional information see, “The Argentine Natural Gas Industry” above.

Austral and San Jorge Basins. Natural gas provided by these basins, located in the southern region of Argentina, was transported mainly by us (Camuzzi Gas del Sur S.A. also transports natural gas through regional pipelines). In the Austral basin, exploration has centered in and around the basin’s existing natural gas fields and on other fields located offshore. The San Jorge basin is primarily an oil-producing basin.

Under the framework enacted by the Government to promote investments after the issuance of Decree No. 929/2013, in 2014, a joint operation was formed by Wintershall Energía S.A., Total Austral S.A. and Pan American Energy LLC Sucursal Argentina for the investment of US$1,000 million in off-shore gas fields (Vega Pleyade) located in the Tierra del Fuego region.

The governments of the provinces on which these basins are located, together with the Government, have taken several measures to develop nonconventional gas and off-shore sites. During May 2019, the Government granted exploration rights to 13 companies over three off-shore basins.

In addition, ENAP Sipetrol Argentina S.A., YPF and IEASA signed an agreement to explore and develop offshore fields in the continental shelf of Argentina, and on September 5, 2019, SHR issued Resolutions No. 524 and 525, which granted an eight-year exploration permit on off-shore areas to Shell Argentina S.A. and QP Oil and Gas S.A.U.

In 2022, Total Austral announced the investment of US$ 700 million in Tierra del Fuego for offshore development (Fenix Project). The project involves the installation of an offshore platform and the construction of 22 miles of subsea pipelines to connect to Vega Pléyade, whose production is in decline. Expected production from the field is approximately 10 MMm3/d. This volume would represent about 8% of the country’s production. The project is expected to be operational in 2025.

The map below illustrates the distribution of the gas basins in Argentina:

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Regulatory Framework

Industry Structure. The legal framework for the transportation and distribution of natural gas in Argentina is comprised by the Natural Gas Law, Decree No. 1,738/92, other regulatory decrees (primarily Decree No. 2255/92, which includes the Basic Rules for Transportation Licenses and Regulations of the Transportation Services), the Pliego, the transfer agreements and the licenses of the newly privatized companies. The Hydrocarbons Law of Argentina regulates the midstream natural gas industry, under a competitive and partially deregulated system. The Public Emergency Law and related laws and regulations, which are no longer in effect, significantly altered the regulatory regime under which we operated since 2002. Notwithstanding this, in December 2019 the national congress passed the Solidarity Law that introduced certain modifications to the RTI concluded in March 2018 with the issuance of Decree No. 250/2018 by the Executive Branch. See “Item 3. Key Information—D. Risk Factors—Risks Relating to Our Business.”

Natural gas transportation and distribution companies operate in an “open access,” non-discriminatory environment under which producers and certain third parties, including distributors, are entitled to equal and open access to the transportation pipelines and distribution system in accordance with the Natural Gas Law, applicable regulations and the licenses of the privatized companies. In addition, a regime of concessions under the Hydrocarbons Law of Argentina is available to holders of exploitation concessions to transport their own natural gas production.

The Natural Gas Law prohibits natural gas transportation companies (TGN and us) from also being merchants in natural gas. In addition, (i) natural gas producers, storage companies, distributors, and consumers who contract directly with producers may not own a controlling interest (as defined in the Natural Gas Law) in a transportation company; (ii) natural gas producers, storage companies and transporters may not own a controlling interest in a distribution company; and (iii) merchants in natural gas may not own a controlling interest in a transportation or distribution company.

Contracts between affiliated companies engaged in different stages in the natural gas industry must be approved by ENARGAS, which may reject these contracts if it determines that they were not entered into on an arm’s-length basis.

ENARGAS, which was established by the Natural Gas Law, is an autonomous entity responsible for enforcing the provisions of the Natural Gas Law, the applicable regulations and the licenses of the privatized companies. Under the provisions of the Natural Gas Law, ENARGAS is required to be governed by a board of directors composed of five full-time directors appointed by the Executive Branch subject to confirmation by the Argentine Congress. However, from 2004 to 2007, ENARGAS was governed by three directors who were not confirmed by the Argentine Congress, and, since 2007, ENARGAS has been administered by an intervention inspector appointed by the Executive Branch for consecutive 180-day terms. After several renewals, the Executive Branch extended its intervention of ENARGAS and appointed a sub-inspector. Finally, on January 31, 2018, through Decree No. 84/2018, the Executive Branch appointed Mauricio Ezequiel Roitman as ENARGAS President for a period of five years, thus terminating the intervention period. However, the Solidarity Law established a new intervention of ENARGAS. Thus, on March 16, 2020, by means of Executive Order No. 278/2020, Federico Bernal was appointed as intervention inspector for a period of one year. ENARGAS’s intervention was extended through Decree 1020.

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ENARGAS has broad authority to regulate the operations of the transportation and distribution companies and has its own budget, which must be included in the Argentine national budget and submitted to the Argentine Congress for approval. ENARGAS is funded primarily by annual control and inspection fees that are levied on regulated entities in an amount equal to the approved budget allocated proportionately to each regulated entity based on its respective gross regulated revenues, excluding natural gas purchase and transportation costs in the case of distribution companies.

Since 2004, the Government adopted a series of measures to redistribute the effects of the crisis in the energy sector caused by the natural gas shortage. Most of the electrical power stations do not have firm gas supply agreements and have increasingly used imported natural gas or alternative fuels that are more expensive than natural gas produced in Argentina. For this reason, ENARGAS and the Federal Energy Bureau (currently, the SHR) have issued a series of regulations aimed at averting a crisis in the internal system of natural gas supply.

The Executive Branch issued Decree No. 181/04, directing the Federal Energy Bureau to establish a system of priority pursuant to which power stations and natural gas distribution companies (for their residential clients) could receive natural gas in priority to other users, even those with firm transportation and firm gas supply contracts. On April 21, 2004, MPFIPyS issued Resolution No. 208/04 that ratified an agreement between the Federal Energy Bureau and natural gas producers to give effect to this new system.

Under certain circumstances and pursuant to the terms of our License, when ENARGAS asks us to restrict the provision of natural gas to clients who hold firm transportation contracts, we are exposed to potential claims from, among others, our customers. Therefore, we have requested that in connection with these new procedures, ENARGAS submit to us written instructions for any such natural gas firm transportation service interruption request. However, in case ENARGAS does not submit such instruction in the way required by our petition and we do not comply with ENARGAS’s instructions, if any, in order to avoid future claims from our customers, Resolution No. 208/04 will require us to pay the price difference between natural gas and the alternative fuel used by power stations in order to offset the loss resulting from our failure to comply with the instructions.

On June 26, 2018, ENARGAS issued Resolution No. 124/2018 which sets modifications to the Dispatch Centers Internal Regulations that establishes the procedures for natural gas dispatch management, modifying the guidelines for the Dispatch Administration attached to the Transport and Distribution Service Regulations and allow full operability of free access with no discrimination and competitive environment, and alternatives which guarantee the quality and continuity of gas transport and distribution public service,  avoiding the cyclical crisis which may affect the transport and distribution systems, seeking to maintain clients supply, by preventing service interruptions with an efficient management methodology.

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Although the natural gas supply shortage did not create a bottleneck in the transportation capacity that prevented the system from meeting increasing demand since 2008, the Government continues to impose restrictions from time to time on the consumption of natural gas by certain customers that hold firm transportation contracts with us, in an effort to redirect and target the supply to the demand regarded as top priority, mainly residential users, CNG stations and industries connected to the distribution network.  Such restrictions have affected direct shippers who have firm transportation contracts with us, as well as industries in different distribution areas of the country.

As of the date of this Annual Report, our compliance has not resulted in legal action initiated by any of our firm transportation clients which could have a significant adverse economic and financial effect on us. However, any legal action, if brought, could have a significant adverse economic and financial effect on us.  See “Item 3. Key Information—D. Risk Factors.”

Our License. Our License authorizes us to provide the public service of natural gas transportation through the exclusive utilization of the southern natural gas transportation system. Our License does not grant us an exclusive right to transport natural gas in a specified geographical area, and licenses may be granted to others for the provision of gas transportation services in the same geographical area. TGN’s natural gas transportation system is operated under a license containing substantially similar terms to those described below and elsewhere herein.

Our License has been granted by the Executive Branch by Decree No. 2451/92 for an original period of 35 years, beginning on December 28, 1992. However, the Natural Gas Law provides that we may request ENARGAS to renew its License for an additional period of ten years. ENARGAS must then evaluate the performance of tgs and raise a recommendation to the Executive Branch. At the end of the period of validity of the License, 35 or 45 years, as the case may be, the Natural Gas Law requires that a new tender be called for the granting of the license. As long as we have substantially complied with our obligations under the License, we have the option to match any offer made by a third party to the Executive Branch.

Our License also places certain other rights and obligations on us relating to the services we provide, including:

• operating and safety standards;

• terms of service, including general service conditions, such as specifications regarding the quality of gas transported, major equipment requirements, invoicing and payment procedures, imbalances and penalties, and guidelines for dispatch management;

• contract requirements, including the basis for the provision of service, e.g., “firm” or “interruptible”;

• mandatory capital investments to be made over the first five years of the license term; and

• applicable rates based on the type of transportation service and the area serviced.

Our License establishes a system of penalties in the event of a breach of our obligations thereunder, including warnings, fines and revocation of our License. These penalties may be assessed by ENARGAS based, among other considerations, upon the severity of the breach or its effect on the public interest. Through Resolution No. 22/2018, ENARGAS adjusted the amounts of fines applicable in the event of a breach of obligations, which amount shall be updated on April of every year. On May 7, 2019, through Resolution No. 251/2019, ENARGAS updated the amounts of the fines up to Ps.21.1 million.

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Revocation of our License may only be declared by the Executive Branch upon the recommendation of ENARGAS. Our License specifies several grounds for revocation, including the following:

• repeated failure to comply with the obligations of our License and failure to remedy a significant breach of an obligation in accordance with specified procedures;

• total or partial interruption of the service for reasons attributable to us, affecting completely or partially transportation capacity during the periods stipulated in our License;

• sale, assignment or transfer of our essential assets or otherwise encumbering such assets without ENARGAS’s prior authorization, unless such encumbrances serve to finance expansions and improvements to the gas pipeline system;

• bankruptcy, dissolution or liquidation; and

• ceasing and abandoning the provision of the licensed service, attempting to assign or unilaterally transfer our License in full or in part without the prior authorization of ENARGAS, or giving up our License, other than in the cases permitted therein.

Our License also prohibits us from assuming debt of, or granting credit to, CIESA, and creating security interests in favor of, or granting any other benefit to, creditors of CIESA.

Generally, our License may not be amended without our consent. As part of the renegotiation of our License under the Public Emergency Law, however, the terms of our License may be changed or our License may be revoked. In addition, ENARGAS may alter the terms of service annexed to our License. If any such alteration were to have an economic effect on us, ENARGAS should modify our rates to compensate for such effect or we could request a change in the applicable rates.

In addition, as licensee for the provision of gas transportation services, we are subject to Law No. 27,437 (Ley de Compre Argentino y Desarrollo de Proveedores), which is regulated by Decree No. 800/2018 and Resolution 91/2018 of Argentine Secretary of Industry. This law provides a regime for purchases from the Government and other concessionaires of public services in Argentina. Pursuant to Article 1 of this law, all public officers, including those in private companies providing public services under licenses and concessions, are required to give preference to the acquisition, lease or lease of goods of national origin.

Decree No. 465/19. On July, 2019, the Executive Branch issued Decree No. 465/2019, which instructed SHR to start a national and international bidding process, to grant a new license for the natural gas transportation system, which includes the construction of a pipeline between Tratayén and Salliqueló (in the Buenos Aires Province) and between Salliqueló and San Nicolás. Through Resolution No. 437 issued on July 30, 2019, SHR called for the bidding process. On April 2, 2020, the Secretary of Energy extended the deadline to submit the bids until December 30, 2020 and announced amendments to the bidding terms and conditions. The Undersecretary of Hydrocarbons and Fuels has been instructed to evaluate other alternatives for the construction of a new gas pipeline and/or the expansion of transportation capacities. On December 30,2020 the Secretary of Energy enacted Resolution No. 448/20 canceled the aforementioned public bidding process.

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Regulation of Transportation Rates—Actual Rates. The natural gas transportation rates established for each transportation company must be calculated in U.S. dollars and converted into pesos at the time of billing. However, the Public Emergency Law eliminated tariff indexing covenants based on U.S. dollar exchange rate fluctuations and established a conversion rate of one peso equal to one U.S. dollar for tariffs.

The rate for natural gas firm transportation services consists of a capacity reservation charge and is expressed as a maximum monthly charge based on the cubic meters per day of reserved transportation capacity. The rate for natural gas interruptible transportation service, which is expressed as a minimum (from which no discounts are permitted) and a maximum rate per cubic meter of natural gas transported, is equivalent to the unit rate of the reservation charge for the firm service based on a load factor of 100%. For both firm and interruptible transportation services, customers are obligated to provide a natural gas in-kind allowance, expressed as a maximum percentage of gas received, equivalent to the natural gas consumed or lost in rendering the transportation service. The rates for all services reflect the rate zone(s) traversed from the point of receipt to the point of delivery.

The table below shows our local natural gas firm and interruptible rates by pipeline and zones, in effect from October 1, 2018, to March 31, 2019, following the issuance of Resolution No. 265/2018 (the “Resolution 265”):

Between October 1, 2018 and March 31, 2019

	Firm	Interruptible
Rate Zones	Reservation Charge(1) (Ps. m3/d)	Minimum Charge(2) (Ps.1,000 m3)	Compression Fuel and Losses(3) (%)

Receipt	Delivery
From Tierra del Fuego to:	Tierra del Fuego	2.115187	70.505443	0.49
	Santa Cruz Sur	4.265351	142.179858	0.98
	Chubut Sur	10.880293	362.676743	3.38
	Buenos Aires Sur	12.818489	427.282869	5.60
	Bahía Blanca	19.634891	654.496272	8.40
	La Pampa Norte	19.565270	652.175202	8.60
	Buenos Aires	22.973029	765.767552	10.35
	Greater Buenos Aires	25.775731	859.191266	11.27
From Santa Cruz Sur to:	Santa Cruz Sur	2.143710	71.456424	0.49
	Chubut Sur	8.749112	291.636962	2.89
	Buenos Aires Sur	10.691453	356.381429	5.11
	Bahía Blanca	17.543207	584.773317	7.91
	La Pampa Norte	17.540057	584.668038	8.11
	Buenos Aires	20.892272	696.408622	9.86
	Greater Buenos Aires	23.703593	790.120501	10.78
From Chubut to:	Chubut Sur	2.126078	70.868874	0.49
	Buenos Aires Sur	3.986437	132.879101	2.71
	Bahía Blanca	10.630388	354.344287	5.51
	La Pampa Norte	11.161907	372.061471	5.71
	Buenos Aires	13.819476	460.647529	7.46
	Greater Buenos Aires	16.477046	549.233587	8.38
From Neuquén to:	Neuquén	1.889165	64.771119	0.49
	Bahía Blanca	9.175905	305.773484	2.80
	La Pampa Norte	9.883458	329.360278	3.15
	Buenos Aires	12.426836	414.138116	3.91
	Greater Buenos Aires	15.221099	508.276603	4.86
From Bahía Blanca to:	Bahía Blanca	2.126068	70.868885	0.49
	La Pampa Norte	0.531517	17.717180	0.20
	Buenos Aires	3.189075	106.303245	1.95
	Greater Buenos Aires	5.846660	194.889310	2.87

(1) Monthly charge for every cubic meter per day of reserved transportation capacity.

(2) Minimum charge equal to the unit rate of the firm reservation charge at a 100% load factor.

(3) Maximum percentage of total transported gas that customers are required to replace in-kind to make up for gas used by us for compressor fuel or losses in rendering transportation services.

Note: The gross receipts tax is not included in such transportation rates.

Source: ENARGAS Resolution 265.

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The table below shows our local natural gas firm and interruptible rates by pipeline and zones, in effect from April 1, 2019, to March 31, 2020, following the issuance of Resolution No. 192/2019 (the “Resolution 192”):

Between April 1, 2019 and March 31, 2020

	Firm	Interruptible
Rate Zones	Reservation Charge(1) (Ps. m3/d)	Minimum Charge(2) (Ps.1,000 m3)	Compression Fuel and Losses(3) (%)

Receipt	Delivery
From Tierra del Fuego to:	Tierra del Fuego	2.665144	88.837143	0.49
	Santa Cruz Sur	5.374436	179.147196	0.98
	Chubut Sur	13.709213	456.974163	3.38
	Buenos Aires Sur	16.151349	538.378143	5.60
	Bahía Blanca	24.740042	824.667950	8.40
	La Pampa Norte	24.652320	821.743392	8.60
	Buenos Aires	28.946110	964.870213	10.35
	Greater Buenos Aires	32.477525	1,082.584470	11.27
From Santa Cruz Sur to:	Santa Cruz Sur	2.701084	90.035383	0.49
	Chubut Sur	11.023917	367.463752	2.89
	Buenos Aires Sur	13.471273	449.042042	5.11
	Bahía Blanca	22.104511	736.816745	7.91
	La Pampa Norte	22.100543	736.684093	8.11
	Buenos Aires	26.324347	877.477681	9.86
	Greater Buenos Aires	29.866623	995.555027	10.78
From Chubut to:	Chubut Sur	2.678866	89.295068	0.49
	Buenos Aires Sur	5.022927	167.428204	2.71
	Bahía Blanca	13.394433	446.475235	5.51
	La Pampa Norte	14.064048	468.798959	5.71
	Buenos Aires	17.412596	580.417750	7.46
	Greater Buenos Aires	20.761144	692.036541	8.38
From Neuquén to:	Neuquén	2.380356	81.611872	0.49
	Bahía Blanca	11.561677	385.275827	2.80
	La Pampa Norte	12.453197	414.995282	3.15
	Buenos Aires	15.657864	521.815701	3.91
	Greater Buenos Aires	19.178646	640.430576	4.86
From Bahía Blanca to:	Bahía Blanca	2.678855	89.295082	0.49
	La Pampa Norte	0.669714	22.323718	0.20
	Buenos Aires	4.018247	133.942519	1.95
	Greater Buenos Aires	7.366815	245.561319	2.87

(1) Monthly charge for every cubic meter per day of reserved transportation capacity.

(2) Minimum charge equal to the unit rate of the firm reservation charge at a 100% load factor.

(3) Maximum percentage of total transported gas that customers are required to replace in-kind to make up for gas used by us for compressor fuel or losses in rendering transportation services.

Note: The gross receipts tax is not included in such transportation rates.

Source: ENARGAS Resolution 192.

No tariff increases have been received between March 1, 2020 and February 28, 2022. On February 1, 2022, ENARGAS provided us with a proposal for a Transitional Renegotiation Agreement (the “2022 Transition Agreement”), which was approved by our Board of Directors on February 2, 2022 and by the different governmental agencies on February 18, 2022. Such agreement was ratified by the PEN through Decree No. 91/2022, effective as of February 23, 2022, which provides a transitional tariff increase of 60% as of March 1, 2022 (the “RTT 2022”).

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On February 25, 2022, Resolution No. 60/2022 of ENARGAS was published in the Official Gazette, whereby it put into effect as from March 1, 2022 the new tariff charts that contemplate the RTT 2022.

Since March 1, 2022

	Firm	Interruptible
Rate Zones	Reservation Charge(1) (Ps. m3/d)	Minimum Charge(2) (Ps.1,000 m3)	Compression Fuel and Losses(3) (%)

Receipt	Delivery
From Tierra del Fuego to:	Tierra del Fuego	4.264230	142.139429	0.49
	Santa Cruz Sur	8.598976	286.635514	0.98
	Chubut Sur	21.934741	731.158661	3.38
	Buenos Aires Sur	25.842158	861.405029	5.60
	Bahía Blanca	39.584067	1319.468720	8.40
	La Pampa Norte	39.443712	1314.789427	8.60
	Buenos Aires	46.313776	1543.792341	10.35
	Greater Buenos Aires	51.964040	1732.135152	11.27
From Santa Cruz Sur to:	Santa Cruz Sur	4.321734	144.056613	0.49
	Chubut Sur	17.638267	587.942003	2.89
	Buenos Aires Sur	21.554037	718.467267	5.11
	Bahía Blanca	35.367218	1178.906792	7.91
	La Pampa Norte	35.360869	1178.694549	8.11
	Buenos Aires	42.118955	1403.964290	9.86
	Greater Buenos Aires	47.786597	1592.888043	10.78
From Chubut to:	Chubut Sur	4.286186	142.872109	0.49
	Buenos Aires Sur	8.036683	267.885126	2.71
	Bahía Blanca	21.430931	714.360376	5.51
	La Pampa Norte	22.502477	750.078334	5.71
	Buenos Aires	27.860154	928.668400	7.46
	Greater Buenos Aires	33.217830	1107.258466	8.38
From Neuquén to:	Neuquén	3.808570	130.578995	0.49
	Bahía Blanca	18.498683	616.441323	2.80
	La Pampa Norte	19.925115	663.992451	3.15
	Buenos Aires	25.052582	834.905122	3.91
	Greater Buenos Aires	30.685834	1024.688922	4.86
From Bahía Blanca to:	Bahía Blanca	4.286168	142.872131	0.49
	La Pampa Norte	1.071542	35.717949	0.20
	Buenos Aires	6.429195	214.308030	1.95
	Greater Buenos Aires	11.786904	392.898110	2.87

(1) Monthly charge for every cubic meter per day of reserved transportation capacity.

(2) Minimum charge equal to the unit rate of the firm reservation charge at a 100% load factor.

(3) Maximum percentage of total transported gas that customers are required to replace in-kind to make up for gas used by us for compressor fuel or losses in rendering transportation services.

Note: The gross receipts tax is not included in such transportation rates.

Source: ENARGAS Resolution 60.

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In addition to the tariffs above, we are entitled to a CAU. Since its inception in 2005, the CAU was increased, by 73.2% on May 1, 2015, and by 200.1% on April 1, 2016, by ENARGAS. We received an additional 50% and 19.7% increase in the CAU on April 1, 2018, and October 1, 2018, respectively. In 2022, we recognized revenues of Ps. 1,410 million as a result of the CAU. The first installment of the tariff increase granted by Resolution 4362 did not include any adjustment of the CAU. Given the permanent increase of operational and maintenance costs throughout the years, which might exceed the amount of the CAU, we filed a claim against the Government to obtain the adjustment of the values and ensure a fair compensation for the service it renders. See “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Pipeline Operations—Pipeline Expansions.”

Tariff situation.

Background and Renegotiation Process

On January 6, 2002, the Argentine Congress enacted the Public Emergency Law, which introduced dramatic changes to Argentina’s economic model, empowering the Government to implement, among other things, additional monetary, financial and foreign exchange measures to overcome the economic crisis in the short-term and bringing to an end the regime established pursuant to the Argentine Convertibility Act, including the fixed parity of the U.S. dollar and the peso. Among others, the Public Emergency Law granted the Executive Branch the power to conduct a renegotiation of public utility contracts and the tariffs set therein. The Public Emergency Law expired on December 31, 2017.

In July 2003, UNIREN was created in order to reach total or partial agreements with the licensees and/or concessionaires of public services and submit proposals regulating the transitory adjustment of tariffs and prices, among other things.  Under this framework, we signed with UNIREN (i) the agreement dated October 9, 2008, between tgs and former UNIREN (the “2008 Transitional Agreement”) that contemplated a tariff increase of 20%, which was not finally implemented as the Government did not issue the corresponding regulatory rules, and (ii) the agreement dated October 2015 between us and the former UNIREN, which incorporated ENARGAS Resolution No. 3347, including, as of May 1, 2015, a transitional increase of 44.3% in the price of the natural gas transportation service and a 73.2% increase in the CAU. Following UNIREN’s failure to comply with certain of its obligations under different renegotiation agreements, we took legal actions against UNIREN.

On February 16, 2016, the Executive Branch issued Decree No. 367/2016, establishing the dissolution of UNIREN and transferring to each ministry the responsibility to renegotiate public service contracts. Decree No. 367/2016 also conditioned the finalization of the new tariff scheme provided in the respective integral renegotiation agreement approved by the Executive Branch to completion of the RTI and provided that transitional adjustment of prices and tariffs are necessary to ensure the continuity of the normal provision of services.

Under the framework of the agreement signed in February 2016 (the “2016 Transitional Agreement”), on March 31, 2016, ENARGAS issued Resolution 3724, which approved revised tariffs as of April 1, 2016, including the CAU, for the Natural Gas Transportation business segment, providing for a 200.1% increase. Additionally, among other things, Resolution 3724 required us to not distribute dividends without the prior authorization of ENARGAS after reviewing our compliance with the transitional mandatory investment plan included in the 2016 Transitional Agreement (the “2016 Investment Plan”). As of the date of this Annual Report, the 2016 Investment Plan is fully executed and has been approved by ENARGAS.

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As several legal proceedings were initiated against Resolution 3724 in order to obtain the annulment of the increase of the PIST and the tariff increases for the natural gas transportation and distribution licensees approved by ENARGAS, we were not able to bill the 200.1% increase in full. On August 18, 2016, the Supreme Court order issued its final decision mandating the Government to (i) implement mandatory public hearings prior to the establishment of natural gas transportation and distribution tariffs, (ii) implement mandatory public hearings prior to the establishment of the point-of-injection gas price and (iii) declare the invalidity of Resolutions 28 and 31 with respect to residential users, for whom tariffs had to be returned to tariff rates effective as of March 31, 2016.

On August 19, 2016, ENARGAS issued Resolution No. 3953/2016, which implemented the decisions arising out of a public hearing before the Supreme Court. For additional information regarding the public hearing’s agenda, see “—Natural Gas Transportation—The Argentine Natural Gas Industry.”

As a result of this public hearing, since October 7, 2016, we were able to collect the revised tariffs at the levels provided for in Resolution 3724, allowing us to complete in full our 2016 Investment Plan.

ICSID Claim

In 2003, Enron, a former indirect shareholder of CIESA, which is our controlling shareholder, and Ponderosa Assets L.P. (“Ponderosa” and, together with Enron, the “Claimants”) filed a claim with the ICSID against the Government under the Bilateral Investment Treaty between the United States and Argentina (the “ICSID Claim”). The ICSID Claim argues that the redenomination of tariffs in pesos (pesificación) and other unilateral changes to our regulatory structure effected by the Public Emergency Law and related laws and decrees violated the requirement of fair and equitable treatment under the treaty. On May 22, 2007, ICSID decided in favor of Enron and ordered the Government to pay US$106.2 million to the Claimants. In July 2010, an ICSID committee annulled the 2007 ICSID resolution. This annulment did not prevent the plaintiff from filing a new claim before the ICSID. On October 18, 2010, Enron Creditors Recovery Corp. (Enron’s new corporate name) and Ponderosa filed a new claim against the Government before the ICSID. In June 2011, a tribunal to hear the case was created.

In January 2011, Pampa Energía acquired, among other assets, (i) PEPCA along with Enron’s and Ponderosa’s economic rights to monitor, suspend and withdraw the ICSID Claim and (ii) from Ashmore Energy International Limited, the financial debt of CIESA and the two derivative transactions originally executed between CIESA and J. Aron & Company on August 3, 2000, and between CIESA and Morgan Guaranty Trust Company of New York on August 4, 2000.

On March 11, 2011, Pampa Energía entered into a call option agreement with the Claimants in order to acquire the rights to monitor, suspend and withdraw the ICSID Claim. On October 6, 2011, we granted a loan for US$26 million to Pampa Energía to enable it to purchase the rights to monitor, suspend and withdraw the ICSID Claim. In 2015, we acquired Pampa Energía’s rights over the ICSID Claim (the “Rights of the Arbitration Proceeding”) from Pampa Energía after certain conditions set forth in the loan agreement were met.

We acquired rights over the ICSID Claim pursuant to a provision in our loan agreement with Pampa Energía, which entitled us to receive the rights as prepayment of the loan if we verified that the 2008 Transitional Agreement had been adequately put into effect. This condition was met with the enactment of Resolutions No. I-2852 and No. 3347. Our rights over the ICSID Claim include the powers to suspend, monitor and withdraw from arbitration proceedings.

The acquisition of the Rights of the Arbitration Proceeding was implemented through the transfer to a trust established outside of Argentina, of which we are the beneficiary.

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On March 27, 2018, the Executive Branch issued the Decree No. 250, which ratified the 2017 Integral Agreement (as defined below). This decree represents the conclusion of the RTI process and the finalization of the agreement signed on March 30, 2017, between tgs and the Government (the “2017 Transitional Agreement”) and, thus, the final renegotiation of our License.

Therefore, on June 26, 2018, as a result of the conclusion of our renegotiations of our License, we, CIESA and its former and current shareholders withdrew all of the legal claims, including the ICSID Claim, filed against the Government related to our business resulting from the Public Emergency Law.

Resolution 74 Tariff Increases

On March 30, 2017, we entered into the Integral Renegotiation Agreement (the “2017 Integral Agreement”) and the related 2017 Transitional Agreement. On the same day and consistent with the 2017 Transitional Agreement, the Ministry of Energy enacted Resolution 74, which increased the price of the natural gas consumed by power plants starting on April 1, 2017 and ENARGAS issued Resolution 4362 by which a new transitional tariff schedule applicable to us determined a total tariff increase of 214.2% and 37%, on the tariff of the natural gas transportation service and the CAU, respectively. However, Resolution 74 provided for a limitation on the full effectiveness of the tariff increase arising from the RTI process until the approvals of the 2017 Integral Agreement were completed. This meant that the tariff increase was granted in three stages on April 1, 2017, December 1, 2017 and April 1, 2018. This staged increase is structured to provide the same economic benefits to us as if the increases had been fully effective since April 1, 2017.

As required by Resolution 74, the first of the tariff increases was granted by Resolution 4362 since April 1, 2017, amounting to 64.2% of our natural gas transportation service tariff. In this opportunity, the CAU was not increased. In addition, pursuant to Resolution 4362, we were required to execute the Five-Year Plan. In addition, Resolution 4362 contemplates a non-automatic semiannual adjustment mechanism for the natural gas transportation tariff and the CAU to reflect changes in WPI, which must be approved by ENARGAS evaluating the evolution of the economic circumstances.

On October 20, 2017, ENARGAS issued Resolution No. 62/2017 by means of which a public hearing was called for November 14, 2017, to address a transitory tariff adjustment on account of the increase foreseen in the tariff review. The public hearing resulted in a transitory tariff adjustment authorized through Resolution 120, which determined an 80.8% increase for the natural gas transportation tariff and 29.7% for the CAU. These new tariff schemes came into effect beginning on December 1, 2017.

A further public hearing in connection with the integral renegotiation was conducted on February 20, 2018, to address (i) a tariff adjustment and (ii) an incremental tariff resulting from the pipeline system expansion project presented by us to ENARGAS on December 19, 2017, involving the building of 47 miles of pipeline extending from the towns of Mercedes and Los Cardales in the Province of Buenos Aires and the installation of a compressor plant at the wellhead. This project would require an initial investment of US$150 million and would allow the incremental transportation of 388MMcf/d of natural gas, with financing through an investment factor (“k” factor).

As a consequence of the public hearing mentioned above, on March 27, 2018, ENARGAS issued Resolution 310, which stated a tariff increase of 50% for the natural gas transportation tariff and the CAU effective as of April 1, 2018.

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On March 27, 2018, through Decree 250, the Executive Branch ratified the 2017 Integral Agreement, following the approval of several governmental authorities, including the Argentine Congress. Decree 250 concluded the RTI process and terminated the 2017 Transitional Agreement, representing the final renegotiation of our License with the Government after 17 years of negotiations. As a result of the foregoing, (i) we were entitled to the final tariff increase contemplated in Resolution 4362 (finally granted by Resolution 310 mentioned above), and (ii) we and our current and former shareholders withdrew any claim against the Government related to our business resulting from the Public Emergency Law, including the ICSID Claim, on June 26, 2018.

On June 21, 2019, SHR issued Resolution 336, through which the payment of 22% of the bills issued from July 1, 2019, to October 31, 2019, to residential customers of natural gas was deferred. Such deferral will be recovered through the bills issued from December 1, 2019, in five consecutive monthly installments. It is expected that the Government will compensate licensors for such deferral. On August 22, 2019, SHR issued Resolution No. 488/2019 (“Resolution 488”), which established the procedure to calculate the deferral provided by Resolution 336. Furthermore, Resolution 488 instructs the implementation of a procedure to calculate and pay the compensation for licensors.

Semiannual Adjustment of Tariffs. Under our License, we may be permitted to adjust tariffs semiannually to reflect changes in PPI and every five years in accordance with efficiency and investment factors to be determined by ENARGAS and, subject to ENARGAS’s approval, from time to time to reflect cost variations resulting from changes in the tax regulations (other than income tax) applicable to us, and for objective, justifiable and non-recurring circumstances.

The Natural Gas Law requires that in formulating the rules that apply to the setting of future tariffs, ENARGAS must provide the transportation companies with (i) an opportunity to collect revenues sufficient to recover all future proper operating costs reasonably applicable to service, as well as future taxes and depreciation, and (ii) a reasonable rate of return, determined in relation to the rate of return of businesses having comparable risk and taking into account the degree of efficiency achieved and the performance of the company in providing the service. No assurances can be given that the rules to be promulgated by ENARGAS will result in rates that will enable us to achieve specific levels of earnings in the future.

However, since January 1, 2000, adjustments to tariffs to reflect PPI variations were suspended, first through an agreement with the Executive Branch and later by a court decision arising from a lawsuit to determine the legality of tariff adjustments through indexes.

Resolution 4362 provided for a semiannual adjustment mechanism based on changes in the WPI. The increase is not automatic, however, as it requires the prior approval of ENARGAS.

On September 4, 2018, a public hearing was held at which we presented a proposed adjustment for our tariffs for the following six months for natural gas transportation service. Finally, on September 28, 2018, ENARGAS issued Resolution 265, which provided an increase of 19.67% over the tariff for the natural gas transport service. This increase came into effect on October 1, 2018.

On February 26, 2019, a new public hearing took place with the aim of establishing the semiannual tariff. On March, 29 2019, ENARGAS issued Resolution 192, which provided an increase of 26% over the tariff for the natural gas transport service. This increase came into effect on April 1, 2019 and was calculated considering the WPI for the period August 2018–February 2019.

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As a consequence of Argentina’s economic condition, and together with other measures taken by the Government, on September 3, 2019, the Secretary of Hydrocarbon Resources (formerly the Federal Energy Bureau) issued Resolution No. 521/2019 – later complemented by Resolution N° 751/2019– which deferred the semiannual adjustment corresponding to October 1, 2019, to January 1, 2020. During 2019 and 2020, according to the RTI, we were entitled to receive two tariff increases, one each year, in order to compensate us for inflation, which affects our operating costs. As of the date of this Annual Report, we have only received a tariff increase in April 2019.

On June 9, 2020, through Resolution No. 80/2020, ENARGAS created the Coordination and Centralization Commission - Law No. 27,541 and Decree No. 278/20, for the purpose of coordinating the comprehensive tariff review process set forth in Article 5 of the Solidarity Law, which provided that natural gas transportation and distribution tariffs were to be maintained without adjustments for a maximum term of 180 days as from December 23, 2019 and empowered the Executive Branch to renegotiate them, either within the framework of the RTI in force or through an extraordinary review pursuant to the provisions of the Natural Gas act.

On June 19, 2020, the Executive Branch issued Decree No. 543/2020 extending the effectiveness of the aforementioned Article 5 for an additional term of 180 calendar days, i.e., until December 16, 2020.

The Solidarity Law and subsequent decrees issued by the Executive Branch determined the freezing of our tariff schedule. In this context, and within the framework of Decree 1020, the Executive Branch started a new RTI process and extended the tariff freeze until transitory tariffs are approved.

Decree 1020 established that the term of the renegotiation may not exceed two years from the effective date of said decree, suspending until then the agreements corresponding to the respective RTI in force with the scope determined in each case by the ENARGAS. The renegotiation process will culminate with the subscription of a final agreement on the RTI.

The Decree 1020 defines ENARGAS to carry out the renegotiation process. Within the renegotiation process, transitory adjustments of tariffs and/or their segmentation may be foreseen, as the case may be. Likewise, it must carry out the relevant and appropriate public hearing, public consultation and citizen participation regimes, as well as give intervention to the Procuración del Tesoro de la Nación and to the Sindicatura General de la Nación. Finally, the resulting agreement must have the corresponding governmental approvals.

On February 17, 2021, by means of Resolution No. 117/2021, the Secretary of Energy called a public hearing for March 15, 2021 in order to discuss the PIST price to be subsidized by the Government of Argentina.

On February 22, 2021, ENARGAS issued Resolution No. 47/2021 by means of which a public hearing was called to be held on March 16, 2021 for the purpose of considering the transition tariff regime in accordance with the provisions of Decree 1020. As foreseen, we have presented at this hearing our proposal for a tariff increase calculated of 58.6%, beginning on April 1, 2021. It has been calculated based on our financial needs to satisfy operating and financial costs, capital expenditures and taxes, which were calculated considering the evolution of the inflation rate for a 12-month period since its inception. This required tariff adjustment does not contemplate any profitability but only the funds necessary to meet these obligations.

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Likewise, in said public hearing, we denied and rejected the arguments put forward in the hearing by which it is considered that the current natural gas transportation rate is not fair, reasonable or transparent, and even mentioned in Decree PEN No. 1020/20, related to the alleged existence of serious defects in the administrative acts resulting from the procedure of the last RTI carried out for us and, in particular, that these defects are based on (i) the manipulation of the updating factor of the capital rate base used for the approval of our rate review; (ii) the lack of motivation and arbitrariness in the choice of the updating factor of the components of the aforementioned rate base structure; (iii) the application of the same factor for all licensees without technical, economic or legal justification since the cost structure of each is different; (iv) the incorrect use of the update factor in the index and the splice used; (v) impediments of a temporary nature that affected the normal development of the comprehensive rate review; and (vi) the exclusion of issues whose temporal timing resulted in the completion of the comprehensive rate review (reduction of percentages of gas withheld). We will vigorously defend our position in any event that the regulator was to impose to us.

On April 28, 2021, ENARGAS sent to us a Draft Transitory Agreement 2021 within the framework of the provisions of Decree No. 1020/2020. This project includes:

• The non-granting of a transitory tariff increase, remaining without variations in the rate charts approved by Enargas in April 2019.

• Establishes that from May 2021 and until the Agreement is in force of Definitive Renegotiation, ENARGAS will proceed to recalculate the rates of transport at that time in force with effect from April 1, 2022.

• Does not establish a mandatory investment plan.

• Provides for the prohibition of: (i) distributing dividends and b) paying in advance financial and commercial debts contracted with shareholders, acquire other companies or give credits.

On April 30, 2021, through a note sent to that body, we stated that, given the context in which it develops its activities and the proposed terms and conditions, it is not feasible for the Company to sign the Draft Temporary Agreement 2021 where it is not recognized any rate increase for the company.

Subsequently, on June 2, 2021, ENARGAS issued Resolution No. 149/2021 that approves a Transition Tariff Regime (the “Transition Regime”) for us with effect from of that date. Said Transitional Regime: (i) does not grant a transitory tariff increase in favor of the Company, but the current rate charts in force since April 1, 2019; (ii) provides that from the entry into force of the Transitional Regime -and until the Definitive Renegotiation Agreement is not in force- the possibility is contemplated that ENARGAS adjusts our rates as of April 1, 2022; (iii) does not establish a new mandatory plan of investments and (iv) establishes the prohibition of distributing dividends and canceling advance financial and commercial debts contracted with shareholders, acquire other companies or grant credits.

In addition, Decree No. 311/2020 (the “Decree 311”, as amended by Decree No. 756/2020), provided for the suspension of the cuts of public utilities for non-payment for a term of 180 days, subsequently extended until December 31, 2020, and the implementation of several measures aimed at sustaining the income of those sectors of the economy that suffer the most from the impact of the crisis. Both the aforementioned and the lockdown measures have implied certain delays in the receipt of collections related to this business segment which, although it has improved recently, it cannot be guaranteed that such situation will be maintained in time.

Subsequently, on February 1, 2022, we received from ENARGAS a proposal for a 2022 Transitional Agreement, which was approved by our Board of Directors on February 2, 2022 and by the different governmental agencies on February 18, 2022. Such agreement was ratified by the Executive Branch through Decree No. 91/2022, effective as of February 23, 2022, which established a 60% tariff increase as of March 1, 2022.

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On February 25, 2022, Resolution No. 60/2022 of ENARGAS was published in the Official Gazette, which put into effect as from March 1, 2022 the new tariff charts that contemplate the 2022 tariff increase.

In accordance with the provisions of the 2022 Transitional Agreement, we committed not to initiate new claims, appeals, actions, lawsuits, or demands of any kind; and/or to suspend, maintain suspended or extend the suspension of all appeals and claims filed that are in any way related to the Renegotiation of the Comprehensive Tariff Review in force, Law No. 27,541, Decrees No. 278/20 and No. 1020/20.

On December 6, 2022, by means of Decree No. 815/2022, the term for the completion of the RTI established in Decree 1020 was extended for a period of 1 year as from its expiration, i.e. until December 18, 2023. It also extends, as from January 1, 2023, the intervention of ENARGAS, which is instructed, while the renegotiation continues, to carry out the necessary measures to achieve a transitional tariff adjustment in accordance with Decree 1020.

Within this framework, on December 7, 2022, ENARGAS issued Resolution 523 by which it called for a public hearing held on January 4, 2023, in order to consider a transitional tariff adjustment of the public natural gas transportation service. In said hearing, in which it was informed that the increase pending application, considering the lack of semiannual adjustments by WPI since April 2019 and the transitory increase granted of 60% as from March 2022, amounted to an estimated 270% as of December 2022, we requested a transitory tariff increase for the year 2023 of 135%, taking into account the current context the country is going through, aiming at the continuity, accessibility and normal provision of the public service of natural gas transportation, in safe conditions, trying to mitigate the economic and financial effects of the higher costs and current expenses associated to the service.

On March 15, 2023, ENARGAS submitted a proposal to tgs for an addendum to the RTI.

On March 16, 2023, our Board of Directors approved the 2023 Transition Agreement sent by ENARGAS. As of the date of this Annual Report the Executive Branch has not ratified the 2023 transition agreement.

The 2023 Transition Agreement has similar conditions to the 2022 Transition Agreement. The 2023 Transition Agreement includes:

- A transitional tariff increase of 95% on the natural gas transportation tariff and the Access and Use Charge.

- With prior authorization from the Ministry of Economy, we are allowed to distribute dividends and to directly or indirectly prepay financial and commercial debts contracted with shareholders, which were previously prohibited by the 2022 Transition Agreement.

Certain Restrictions with Respect to Essential Assets. A substantial portion of the assets transferred by GdE were defined in our License as essential to the performance of the licensed natural gas transportation service. Pursuant to our License, we are required to segregate and maintain the essential assets, together with any future improvements thereon, in accordance with certain standards defined in our License.

We may not for any reason dispose of, encumber, lease, sublease or lend essential assets for purposes other than the provision of the licensed service without ENARGAS’s prior authorization. Any extensions or improvements that we make to the natural gas pipeline system may only be encumbered to secure loans that have a term of more than one year to finance such extensions or improvements.

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Upon expiration of our License, we will be required to transfer to the Government or its designee the essential assets specified in our License as of the expiration date, free of any debt, encumbrance or attachment. If we decide not to participate in a new bidding for a new License term, we will receive compensation equal to the lower of the following two amounts:

• the net book value of the essential assets determined on the basis of the price paid by CIESA for shares of our common stock plus the original cost of subsequent investments carried in U.S. dollars in each case adjusted by the PPI, net of accumulated depreciation in accordance with the calculation rules to be determined by ENARGAS (since the enactment of the Public Emergency Law, this provision may no longer be valid); or

• the net proceeds of a new competitive bidding (the “New Bidding”).

Once the period of the extension of the License expires, we will be entitled to participate in the New Bidding, and, thus, we shall be entitled to:

• submit a bid computed at an equal and not lower price than the appraisal value determined by an investment bank selected by ENARGAS, which represents the value of the business providing the licensed service at the valuation date, as a going concern and without regard to the debts;

• match the best bid submitted by third parties in the New Bidding, if it would be higher than our bid mentioned above, paying the difference between both values to obtain a new license; and

• if we have participated in the New Bidding but are unwilling to match the best bid made by a third party, receive the appraisal value as compensation for the transfer of the essential assets to the new licensee, with any excess paid by the third-party remaining for the grantor.

Under Argentine law, an Argentine court will not permit the enforcement of a judgment on any of our property located in Argentina which is determined by the courts to provide essential public services. This may adversely affect the ability of a creditor to realize a judgment against our assets.

Under a transfer agreement we entered into in connection with the privatization of GdE in the 1990s (the “Transfer Agreement”), liabilities for damages caused by or arising from the GdE assets are allocated to either GdE or us depending on whether any such damage arose or arises from the operation of the assets prior to or following the commencement of our operations. Also, pursuant to the Transfer Agreement, we are responsible for any defects in title to such assets, although any such defects are not expected to be material. The Transfer Agreement further provided that GdE was responsible for five years until December 1997 for the registration of easements related to the system, which were not properly recorded, and for the payment to property owners of any royalties or fees in respect thereof. Since 1998, we have been responsible for properly recording any remaining easement agreements and for making payments of royalties or fees related to such easements.

Environment

Environmental matters of the natural gas transportation business are governed by regulation NAG153 (as described below) issued by ENARGAS, which sets the guidelines for the implementation of an environmental management system and for the obligation to evaluate the environmental impact of projects.

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Our business activities primarily have an impact on the atmosphere (as a result of methane release and combustion gases), the soil and watercourses due to the pipelines (including maintenance, third parties’ actions or failures). Our activities also generate hazardous waste and environmental noise. Further, we may be required to handle universal archeological or paleontological findings during works. All these aspects are monitored and measured under our comprehensive environmental program. We also conduct an annual emergency drill program to test our response capacity under safety and environmental emergencies, the 2021 drill was completed with satisfactory results. Our policy also extends to our contractors, who are required to comply with the same standards and implement environmental protection measures for the execution of each work.

See “Item 4. Our Information—D. Property, Plant and Equipment—Environmental, Social and Governance.”

Competition

Our Natural Gas Transportation business provides an essential public service in Argentina in accordance with Article No. 1 of the Natural Gas Law. Although there are no regulatory limitations on entry into the business of providing natural gas transportation services in Argentina, the construction of a competing pipeline system would require substantial capital investment and the approval of ENARGAS. Moreover, as a practical matter, a direct competitor would have to enter into agreements with natural gas distribution companies or end-users to transport a sufficient quantity of natural gas to justify the capital investment. The building and operation of a natural gas pipeline requires important technical know-how and high investment levels.

Also, the ability of new entrants to successfully penetrate our market would depend on a favorable regulatory environment, an increasing and unsatisfied demand for natural gas by end-users, sufficient investment in downstream facilities to accommodate increased delivery capacity from the natural gas transportation systems and the finding of significant natural gas reserves. Given the potential of Vaca Muerta’s non-conventional gas formation, other competitors, new market participants or even us in association with third parties may become interested in participating in the construction of new similar projects that could have an impact on our competitive position and on our financial situation and future results.

To a limited extent, we compete with TGN on a day-to-day basis for natural gas interruptible transportation services and, from time to time for new natural gas firm transportation services made available as a result of expansion projects to the natural gas distribution companies to whom both we and TGN are either directly or indirectly connected (Camuzzi Gas Pampeana S.A., Metrogas S.A. and Naturgy Argentina S.A.). We compete directly with TGN for the transportation of natural gas from the Neuquina basin to the greater Buenos Aires area.

The cost of natural gas relative to competing fuels may also affect the demand for transportation services in the long-term. The delivered cost of gas to end-users in Argentina, based on energy content, is currently significantly lower than other alternative fuels, except for hydroelectric power.

In 2008 and 2010, the Government, through IEASA, completed the construction of two natural gas regasification ports in Bahía Blanca and Escobar, province of Buenos Aires, which are intended to supplement the natural gas supply deficit. In order to supply the peak demand in winter, YPF and IEASA launched a process tender for the acquisition of a LGN regasification vessel in Bahía Blanca as has been carried out in the past. Finally, the Ministry of Energy announced Excelerate as the winner of the aforementioned tender.

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In addition, the Argentine Government has launched a series of projects to promote the exploration and development of new natural gas reserves.

Through Resolution No. 1036/2021, published in the Official Gazette on November 1, 2021, the Secretary of Energy approved the “Guidelines for an Energy Transition Plan to 2030” where the objectives and characteristics of the Argentine energy matrix and the main action guidelines to comply with them are formulated.

The abovementioned Resolution incorporates the Energy Transition Program, which establishes a series of general objectives and strategic guidelines for 2030 in energy matters. Regarding the guidelines, the program includes energy efficiency; clean energy in greenhouse gas (GHG) emissions; gasification; development of national technological capacities; resilience of the energy system; federalization of energy development; national strategy for the development of hydrogen.

Within this framework, on February 11, 2022, Resolution 67 was published, which created the Transport.Ar Program whose main purpose is to promote the development and growth of natural gas production and supply.

The program is aimed at the development of different economic and industrial aspects. In particular, within the framework of such development, it aims at: (i) the growth of natural gas production and supply; (ii) the substitution of LNG and Gas Oil - Fuel Oil imports; (iii) ensuring energy supply and guaranteeing domestic supply; (iv) increasing the reliability of the energy system; (v) optimizing the national transportation system; (vi) increasing natural gas exports from neighboring countries; and (vii) tending to regional gas integration.

Among the works included in the program are:

• NK pipeline.

• Construction of the gas pipeline between the cities of Mercedes and Cardales in the Province of Buenos Aires.

• Expansion of NEUBA II Gas Pipeline: loops and compressor plants.

• Reversion of the North Gas Pipeline Stages I and II.

• Expansion of the Central West Gas Pipeline: different sections between the Neuquén and Litoral areas in the Province of Santa Fé.

• Expansion of the final sections of gas pipelines in AMBA.

Also, the following additional works to be executed in subsequent stages are included:

• Expansion of the transportation capacity of the Gasoducto del Noreste Argentino (GNEA) by compression increase.

• GNEA - San Jerónimo connection from the cities of Barrancas to Desvío Arijón in the Province of Santa Fé.

• Construction of loops and compression in Aldea Brasilera (Entrerriano Gas Pipeline).

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• Expansion of the transportation capacity of the General San Martín Gas Pipeline.

• Execution of Stage III “Mesopotamia” of the Gas Pipeline of Northeastern Argentina (GNEA) in the Provinces of Corrientes and Misiones.

Also, by means of Decree No. 76/2022 of February 11, 2022, the concession of the NK Pipeline was granted to IEASA for a term of 35 years and the trust FONDESGAS (Fondo de Desarrollo Gasífero Argentino) was created, with IEASA as trustee and beneficiary, and BICE as trustee.

The construction of the NK Pipeline, and its complementary works, is of vital importance for the Argentine energy development and in a first stage it will connect the town of Tratayén in the Province of Neuquén with the town of Salliqueló in the Province of Buenos Aires, where it will be connected to the gas pipeline system operated by us. The second stage will consist of the construction of the gas pipeline section to San Jerónimo in the south of the Province of Santa Fé.

The works will be carried out by IEASA, which will be able to do it by itself or through third parties, with priority to YPF. In the event that for the execution of the works the ES opens a call for bids, we will evaluate the convenience of participating in the provision of the operation and maintenance service.

If this or an alternative project continues and is awarded to another company, then we will compete on a day-to-day basis for natural gas, interruptible transportation services and, from time to time, for new natural gas firm transportation services made available as a result of future expansion projects to transport nonconventional natural gas from the Vaca Muerta area.

In addition, the Government has implemented a number of projects to encourage the exploration and development of new natural gas reserves, or secure alternative supplies of natural gas, in recent years.  See “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—The Argentine Natural Gas Industry.” For example, the Northeast pipeline is a project, led by the Government, which will connect the Bolivian natural gas basins with the northeastern region of Argentina and the greater Buenos Aires region. In recent years, the Government has carried out, albeit with some delays, the development of the expansion works.

LIQUIDS PRODUCTION AND COMMERCIALIZATION

Our Liquids production and commercialization activities are conducted at our Cerri Complex, which is located near the city of Bahía Blanca in the Province of Buenos Aires. In the Cerri Complex, ethane, LPG and natural gasoline are extracted from natural gas, which arrives through our three main pipelines from the Neuquina and Austral natural gas basins.

We own the Liquids obtained at our Cerri Complex. We purchase natural gas in order to replace thermal units consumed in the Liquids production process. These natural gas purchases are negotiated with certain natural gas distributors, traders and producers. The results of our Liquids Production and Commercialization segment are subject to risks associated with commodity price changes.

During 2022, 2021 and 2020, all of our Liquid sales were on our own account. Our sales of Liquids in the domestic market are regulated through the Households with Bottles Program (as defined below) of the Ministry of Energy in order to guarantee the supply at reasonable prices. For more information, see “—Regulation—Domestic market” below.

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Liquids production in 2022 reached 1,122,639 tons, an increase of 2,493 tons or 0.2%, with respect to Liquids production in 2021. During 2022, there were no production restrictions during the winter period. The reduction in volumes produced was mainly due to the reduction in demand ethane and LPG in the domestic market, partially offset by the increase in volumes exported.

In 2022, we were the second ethane producer behind MEGA, and our market share increased to more than 40% of the total ethane produced in Argentina in that year. The graphs below show our share in total propane and butane production in Argentina during 2022:

 

During 2022, propane and butane deliveries to the export market were operated on a spot basis, capturing opportunities associated with different market niches, which allowed for a considerable increase in the individual fixed premiums of each operation. We also continue to advance its positioning in the Brazilian market by maintaining direct maritime exports (without intermediaries) to Brazilian LPG distributors, which began in 2021. In addition, in September 2022, the first direct maritime export to a Brazilian industrial user was carried out. In addition, in December 2022, we carried out the largest LPG export by sea for private Brazilian companies.

With respect to the export of natural gasoline, during 2022 and until February 2023, such gasoline was commercialized through a contract entered with Trafigura Pte Ltd. at the international price less a discount. As of the date of issuance of this Report, a new contract was entered into with Trafigura Pte Ltd. which is valid until February 2024. This contract has similar conditions to the contract in force during 2022, although it has a greater discount in the international price received.

For additional information regarding Liquids price evolution during the years 2022 and 2021 see “Item 5. Operating and Financial Review and Prospects—A. Operating Results.”

Truck exports to neighboring countries have also grown. The countries with which we operate under this scheme are Chile, Paraguay and Brazil. Although volumes exported using this modality are much lower than exports by sea, they allow us to obtain a larger profit margin.

During 2022, we continued to market LPG through the land mode, dispatching approximately 16,156 trucks (372,813 tons) of own product, compared to approximately 17,348 trucks (410,029 tons) of own product dispatched during 2021.

Our entire ethane production is sold to PBB through a long-term agreement signed on September 6, 2018. This agreement will expire on December 27, 2027 and includes, among other conditions, TOP and DOP commitments for minimum annual per year, which is lower than the TOP quantities included in the 2015 ethane agreement with PBB. If either of the parties does not comply with the TOP or DOP conditions, as applicable, that party is required to compensate the other party for the breach of the minimum annual quantities commitment. Pursuant to the current contract with PBB, in case of a default by PBB with respect to its TOP commitments, PBB will be required to compensate us.

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Our Liquids Production and Commercialization segment also comprises storage and dispatch by truck and subsequent shipment of the liquids extracted at the Cerri Complex to facilities located in Puerto Galván. LPG and natural gasoline are transported via two eight-inch pipelines to the loading terminal at Puerto Galván. Ethane is piped via an eight-inch pipeline to the PBB olefins plant, which is the sole outlet for ethane from the Cerri Complex. Any ethane extracted at the Cerri Complex that cannot be sold to PBB is reinjected into the pipeline.

Our Liquids Production and Commercialization segment has increased as a percentage of our total revenues from 19.0% in 2001 to 64% in 2022, as a consequence of the adverse change in the regulated Natural Gas Transportation segment, and the increases in the international prices of LPG and natural gasoline, which generated higher revenues primarily from exports.

In 2022, our export revenues from the Liquids Production and Commercialization segment were Ps. 46,314 million and represented 28% of our total revenues and 44% of our liquids production and commercialization revenues. Additionally, the total volume of sales from Liquids was 1,129,004 tons, and the volume of sales from Liquids exports was 398,547 tons, representing 35% of our total liquids sales volumes.

The annual sales of our Cerri Complex for 2022, 2021 and 2020 in tons were as follows:

	2022		2021		2020
Ethane		329,232		353,078		360,870
Propane		410,563		383,085		391,636
Butane		263,932		267,579		270,669
Natural Gasoline		125,277		115,677		122,197
Total		1,129,004		1,119,419		1,145,372

We anticipate that new oil and natural gas developments in Argentina will provide new opportunities in the Liquids Production and Commercialization business and lead to related increases in revenues from our Natural Gas Transportation and Liquids Production and Commercialization businesses.

Regulation

Liquids production and commercialization activities are not subject to regulation by ENARGAS. However, in recent years, the Government has enacted regulations that significantly affect our Liquids production activities.

Domestic market

We are not able to freely select the markets to which we will allocate LPG production. As we are effectively required to meet the minimum domestic demand before exporting significant amounts of LPG, we forego sales to foreign markets, where the prices for some products are higher than those established for local consumers in Argentina.

On March 9, 2005, the Government enacted Law No. 26,020, which set forth the regulatory framework for LPG industry and commercialization. After its issuance, the Ministry of Energy established, through several subsequent resolutions, reference prices applicable to sales of LPG bottles.

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On March 30, 2015, the Executive Branch issued Decree No. 470/2015, regulated by Resolution No. 49/2015 issued by the former Federal Energy Bureau, both creating the framework for selling LPG bottles (the “Households with Bottles Program”) which replaced the programs in force until that time.

The provisions of Law No. 26,020 set the sales prices of LPG for the local market and the SHR is the body that periodically determines the minimum volume of product that each producer must allocate for commercialization in order to ensure domestic supply. The former Federal Energy Bureau established, through several resolutions, reference prices applicable to sales of LPG containers of less than 45 kilograms and to wholesale LPG sales exclusively to LPG retailers (fraccionadores).

Under the Households with Bottles Program the Ministry of Energy regulates the price and the quantity of LPG sold in the domestic market by each LPG producer. The compensation received from the Ministry of Energy was Ps.550 per ton of butane from April 2015 through March 2018. Afterwards, on March 27, 2018, the SHR issued Resolution No. 5/2018 increasing the price paid under the Households with Bottles Program to Ps.5,416 per ton of butane and Ps.5,502 per ton of propane, effective as of April 1, 2018.

During 2019, the Government introduced several amendments to the prices of the products commercialized under the Households with Bottles Program. The prices per ton of butane and propane increased as follows: (i) from February 1, 2019 to May 10, 2019, to Ps.9,154 and Ps.9,042 respectively, (ii) from May 10, 2019 to June 30, 2019, to Ps.9,327 and Ps.9,213 respectively, and (iii) since July 1, 2019, to Ps.9,895 and Ps.9,656 respectively. On October 19, 2020, the Secretary of Energy issued Resolution No. 30/2020 by which it increased the price of such products to Ps.10,885. Furthermore, since February 1, 2019 the compensation received through the Households with Bottles Program was completely eliminated.

More recently, through Resolution No. 249/2021, the Ministry of Energy increased the price of the products contributed to this program from April 2021 to Ps.12,627.

In 2022 the price of the products contributed to this program were increased by Resolutions No. 270/2022, 809/2022 and 861/2022. Back in December 2022, the price per ton of butane and for propane was Ps. 26.800,8.

Then on August 25, 2021, the Secretary of Energy issued Resolution No. 809/2021 which establishes a Temporary Economic Assistance addressed to LPG industry operators (producers, fractionators and distributors). The Transitional Economic Assistance provides for the recognition of 20% of the LPG sales invoiced for the Home Program for the period from August to December 2021, subsequently extended until March 31, 2022. On April 22, 2022, this assistance has been extended until December 31, 2022.

The Households with Bottles Program requires us to produce, under certain circumstances, and market the LPG volumes required by the Ministry of Energy at prices significantly below the market. This requirement might prevent us from covering production costs, even after giving effect to the subsidy payments that we receive under the agreement, creating a negative operating margin. We have initiated several actions with the Government in order to enjoin the requirement that we sell products with negative operating margins for an extended period. On June 3, 2015, we filed a motion for reconsideration regarding the volumes of LPG that we were required to provide in 2015 under the Households with Bottles Program. In addition, on August 18, 2015, we filed a lawsuit to overturn Resolutions No. 49/15 and 70/15 which implemented the Households with Bottles Program and required us to sell products below their international reference prices. Since the Macri administration took office, prices of products sold under the Households with Bottles Program have been adjusted and we did not continue pursuing legal actions against Resolutions No. 49/15 and 70/15.

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On March 16, 2015, through Resolution No. 36/2015, which modified Resolution No. 792/05, the Ministry of Energy set the method to calculate the LPG export parity that would be updated monthly by this agency. These modifications generated an increase in the prices at which the LPG is sold in the local market to those customers who do not fall under the Households with Bottles Program and the Propane for Networks Agreement.

Since the Propane for Networks Agreement was signed between the Government and producers of LPG, including us, in 2003, we have complied with our commitments under that agreement. Pursuant to the Propane for Networks Agreement, which has been extended several times, the Ministry of Energy fixed prices and procedures by which it compensates participating companies. The compensation received is calculated as the difference between the sales price established for the domestic market and the LPG export parity price published monthly by the Ministry of Energy. The compensation is calculated on a monthly basis.

The Propane for Networks Agreement, which served as a framework for the marketing of the products stipulated therein, has been extended several times. The latest extension will be in force until December 31, 2022.

The Government compensates us for our participation in the Propane for Networks Agreement. During 2022, these collections have suffered significant delays. As of December 31, 2022, we had Ps. 3,768 million in receivables against the Government in connection with the Households with Bottles Program and the Propane for Networks Agreement.

International Market

In the international market, we commercialize propane, butane and natural gasoline to international traders and other clients.

On September 4, 2018, by means of Decree No. 793/2018 (later amended by National Executive Branch Decree No. 865/2018, the effectiveness of which was ratified by Law No. 27,467), the National Executive Branch stipulated a 12% withholding on exports for all the goods comprised in the common customs MERCOSUR nomenclature, with a maximum of Ps.4 per Dollar for the products that our Company exports. This price limit was left without effect on December 16, 2019 pursuant to Decree No. 37/2019.

Through Law No. 27,541, the Executive Branch (until December 31, 2021) is empowered to set export duties, the rate of which may in any case not exceed 33% of the taxable value price. Beyond the general limit mentioned above, with respect to hydrocarbons, it is established that withholding tax may not exceed 8% of the taxable value price.

On May 19, 2020, the Government issued Decree No. 488/2020 (“Decree 488”) pursuant to which, among others, the price per barrel of crude oil in the local market was fixed at US$45 until December 31, 2020, subject to review if the “ICE Brent first line” price exceeds US$45 / bbl during 10 consecutive days, and introduced modifications to the tax regime applicable to domestic consumption of fuel and export withholdings.

During fiscal year ended December 31, 2022, the withholding tax rate reached the maximum amount of 8%.

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Environment

In addition to this sector-specific regulation, we must comply with the environmental legislation set by each of the seven provinces where the high-pressure trunk gas pipeline system runs.

Our production and liquid storage facilities are subject to Law No. 11,459 of industrial establishment of Buenos Aires. Additionally, we must comply with all environmental legislation issued by the province, which includes laws and regulations of gas emissions, waste emissions, use of public waters and return of effluents, among others. Both facilities in the Cerri Complex and Puerto Galván have valid environmental certificates.

See “Item 4. Our Information—D. Property, Plant and Equipment—Environmental, Social and Governance.”

Competition

The construction and operation of natural gas processing plants located in the Province of Neuquén have represented important competition for our Liquids sector, since our customers could satisfy their product demand with alternative suppliers. This competition was finally mitigated by entering into agreements with natural gas producers that limited their ability to make investments in natural gas processing plants.

For example, at the end of 2000, MEGA finished building and began operation of a gas processing plant with a capacity of approximately 1.3 Bcf/d, located in the Province of Neuquén. Although the construction of this gas processing plant initially resulted in lower volumes of gas arriving at the Cerri Complex, we have been able to undertake measures to substantially mitigate any negative impact of MEGA’s activity. However, there is a risk that additional gas processing at the MEGA plant could result in lower volumes or lesser quality gas (i.e., gas with lower liquids content) arriving at the Cerri Complex in the future, or that other projects that may be developed upstream of the Cerri Complex could adversely affect our revenues from Liquids production and commercialization services.

Formerly, our sole purchaser of ethane, PBB, decided, for commercial reasons, to give priority to the product provided by MEGA. If PBB continues with its policy of taking increased volumes of ethane from our competitors, this situation could adversely affect our revenues from Liquids production and commercialization services, if we are unable to sell the ethane and must reinject it into the gas stream.

In order to guarantee access to natural gas not yet processed in the Cerri Complex, in the past, we obtained the commitment of natural gas producers to not build natural gas processing plants upstream of the Cerri Complex during the term of such long-term agreements. From time to time, and as these contracts expire, we renew and sign new agreements with them to replace expiring contracts. The agreements reached in more recent years, have had shorter durations and the contracts in effect do not limit the ability of gas producers to build natural gas processing plants upstream of the Cerri Complex during the term of the agreement. All of these recent agreements contain commitments of such natural gas producers not to reduce the quality of the natural gas that they sell to us. Nevertheless, any decision by such natural gas producers to make modifications to the methodology for injecting natural gas into the pipeline system could result in the receipt of lower quality natural gas, thereby reducing the amount of Liquids available for extraction and processing in the Cerri Complex.

OTHER SERVICES

Other business activities are not subject to regulation by ENARGAS.

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Midstream Services

Through midstream services, we provide integral solutions related to natural gas from the wellhead up to the transportation systems. The services comprise gas gathering, compression and treatment, as well as construction, operation and maintenance of plants and pipelines, which are generally rendered to natural gas and oil producers at the wellhead. Our portfolio of midstream customers also includes distribution companies, big industrial users, power plants and refineries. Our midstream activities also include the separation and removal of impurities such as water, carbon dioxide and sulfur from the natural gas stream, and steam generation for electricity production. Small diameter pipes from the wellheads form a network, or gathering system, carrying the gas stream to larger pipelines where field compression is sometimes needed to inject the gas into our large diameter gas pipelines. The services are tailored to fit the particular needs of each customer in technical, economic and financial matters.

This business segment includes the transportation and all related services provided in Vaca Muerta after the important gas pipe project carried out during 2019 which allow us to comply with the agreements signed with the main natural gas producers in the area.

In addition, we provide operation and maintenance of pipelines services to our affiliate Gas Link S.A. (“Link”).

In September 2017, the UT Río Neuquén was created by YPF, Pampa Energía and Petrobras Brazil, to expand for the next ten years, the services provided at the Río Neuquén Plant. A natural gas dehydration unit with capacity of 71 MMcf/d has been installed and several minor modifications in the plant have been performed.

We have entered into an UT with SACDE for the purpose of participating jointly in the National Public Bid No. 452-0004-LPU17: Assembly of Pipes for the Construction of the Project “Expansion of the Natural Gas Transportation and Distribution System.” As a result of this bid, the Ministry of Mines and Energy awarded to the aforementioned UT the contract for the construction of the Regional II-Recreo/Rafaela/Sunchales Regional Gas Pipeline. As of the date of issuance of this Annual Report, construction works are in progress.

Furthermore, we aim to have a leading role in the development of Argentina’s energy sector. For this reason, we developed projects in the Southern Section and Northern Section in the Vaca Muerta fields. To make these investments viable, we executed agreements with various natural gas producers and contracted natural gas treatment services for a period of 10 years.

The total investment in both the Northern Section and the Southern Section of the pipeline gathering system and the natural gas conditioning plant located at the ending point of both sections was US$260 million, and may potentially amount to up to US$800 million in case there is a decision to expand and make the plant capacity match the gathering pipeline capacity. The 91 miles gathering pipeline formed by the Northern and Southern Sections will capture and transport the natural gas production of eight hydrocarbon areas within the Vaca Muerta play. The natural gas pipelines have a transportation capacity of 60 MMm3/d and the conditioning plant has a capacity of 15 MMm3/d.

Additionally, the connection of the plan located in Tratayén to the Central West Gas Pipeline, belonging to TGN’s regulated transportation system, was completed in 2020.

This project will continue to improve the profitability of the investment made by us and generate business alternatives necessary for the sustainable development of the area by natural gas producers, particularly by providing security in the evacuation of gas volumes committed by some customers under the Gas.Ar Plan.

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In June 2020, two agreements were signed to provide in the Plaza Huincul Plant, the service of compression and conditioning of gas from the Cerro Bandera field - signed with Oilstone Energía S.A. (“Oilstone”) in its role as operator of the Cerro Bandera concession - and from the Puesto Cortadera and Portezuelo Minas fields - signed with Oilstone in its role as operator of the Unión Transitoria de Empresas (Joint Venture) called Gas y Petróleo del Neuquén S.A. - Oilstone - Dorsal - Unión Transitoria -, both for a seven-year term. In order to provide this service, a third agreement was signed with Oilstone whereby we executed the hydraulic test and connection works between an Oilstone gas pipeline and our compression and conditioning plant. On September 28, 2020 we completed these works and in October 2020 the compression and conditioning service described above commenced.

As a consequence of the increase in natural gas production levels recorded in the Neuquina basin, we have recorded increasing levels of utilization of midstream facilities; this is mainly evident in the Vaca Muerta System, which started 2021 capturing and treating flows of around 3.5 MM3/d at the Tratayén plant and ended this year with flows of around 9 MM3/d. To cope with this flow growth, expansion works were carried out at the Tratayén Plant, which had been approved in 2020. These works, completed in September 2021, involved the installation of a new slug catcher and a new stabilizing tower.

This effort was accompanied by the negotiation and closing of new service contracts (transportation and conditioning) with Shell Argentina and YPF in Bajada de Añelo and with Pampa Energía in El Mangrullo.

As for the Río Neuquén Plant, during the year 2021 this facility saw an increase in incoming natural gas flows, which opens auspiciously opportunities to increase the services provided therein with potential capacity expansions.

During February 2023, we concluded the expansion works in Tratayén started in 2022 that consisted in the Installation of two modular gas conditioning plants through Joule Thomson technology, each with a capacity to treat 3.5 MM3/d of natural gas and of a new gasoline stabilizing tower. This project is involved an estimated investment of US$32 million.

New Projects

Our strategy of focusing on the customer and innovation makes us focus on generating business and investment alternatives that allow us to make our investment profitable and thus provide value to our shareholders. Thus, we approved a series of investment projects that will allow us to expand the capacity of the Tratayén Plant:

- Installation of a conditioning plant with a capacity of 6.6 MMm3/d, which will require an estimated investment of US$ 132 million, with start-up scheduled for December 2023.

- Installation of a second conditioning plant with a capacity of 6.6 MMm3/d, which will require an estimated investment of US$ 138 million, with start-up scheduled for mid-2024.

These projects will increase the capacity to provide services to the Vaca Muerta System, improving the profitability of the investment made by us and providing security in the evacuation of gas volumes from producers.

They also reinforce our commitment to Argentina’s energy development and our strategy of making the investments made in the installation of the Vaca Muerta gas pipeline system profitable. In this sense, we continue in conversations with the different producers in the basin in order to capture business opportunities that will allow us to increase our portfolio of services and client portfolio.

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Telcosur (Telecommunications System)

  We own 99.98% of Telcosur, a telecommunications company created in September 1998 to provide value-added and data transportation services using our modern digital land radio telecommunications system with Synchronous Digital Hierarchy (“SDH”) technology (which was installed for purposes relating to our gas transportation system).

With respect to the telecommunications services provided by Telcosur, during the year 2022, agreements were reached that allowed increasing the capacity sold and consolidating the Company’s operations.

In line with the strategy of consolidating the business in the medium and long-term, Telcosur reached agreements with new customers and was able to expand or renew existing agreements. Among the most relevant agreements entered into, we can mention the following:

Agreement with Shell Argentina S.A. (“Shell”)

During 2022 Telcosur entered into an agreement with Shell to link its plants in Bajada de Añelo and Sierras Blancas and its corporate network. The agreement consists of the provision of a data and internet transport service between the aforementioned plants for the operational management of the work. This agreement also involves the construction of a new fiber optic section through the access road to Tratayén, to reach Shell’s Sierras Blancas plant.

Agreement with Vista Oil & Gas Argentina (“Vista”)

The project consisted in the optical fiber linking of Telcosur’s infrastructure in Tratayén with Vista’s infrastructure in the Borde Montuoso field.

Since the link was originally necessary for the gas pipeline connection between we and Vista, Telcosur participated in the engineering definitions of such work in order to make available an extension of the fiber optic network of both parties with the purpose of generating the technical conditions to close the internet sale business. The execution of this project involved the linking of Telcosur’s fiber optic network with Vista’s network.

Agreement with Pampa Energía - El Mangrullo Oilfield (“EMA”)

The project consisted in linking Telcosur’s fiber optic infrastructure in Tratayén with Pampa Energía’s infrastructure in El Mangrullo oilfield. In this opportunity, the linking point was defined in the Vaca Muerta Sur gas pipeline.

In parallel with this network connection, an agreement was reached for the provision of internet service within the oilfield.

In addition, and thanks to the works mentioned above, an agreement was reached with Claro Argentina S.A. (“Claro”) to replace its satellite link for the transport of data from the mobile radio base that was previously in the field, and thus provide a better service to Pampa Energía at the site.

Additionally, an annual maintenance agreement was reached with Pampa Energía.

Installation of fiber optic network in Vaca Muerta

During 2022, work progressed on the installation of a high capacity fiber optic network from Vaca Muerta Norte to Los Toldos for an extension of more than 20 miles, to provide telecommunications services to oil and gas producers and service companies in Vaca Muerta, which require a significant amount of data transmission for their operations and communications.

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In 2022, the fiber optic capacity was expanded in Vaca Muerta, making it possible to provide point-to-point or multipoint solutions with constant speed and high capacity, and due to its characteristics with the integration of voice, data, internet and video, it allows optimizing costs.

New technologies

Progress was made with “IoT” radio bases to expand Telcosur’s portfolio of services provided to its customers. Augmented Reality and Drone services were added to Telcosur’s service portfolio.

In addition, the radio transmission system was expanded between the mainland and Tierra del Fuego, which increased network capacity and made a service agreement with new customers viable. In order to provide capacity in Río Grande to meet the demands of customers such as Total, Carrier, YPF, Cirion, CGC and Telecom, among others, a fifth radio beam was added between the stations El Cóndor and Cañadón Alfa, which will increase the capacity of the Río Gallegos to Rio Grande section by approximately 200 MbPs. In addition, a fiber optic link between Río Gallegos and El Cóndor was enabled to transport 1 Gbps circuits.

C. Organizational Structure

The following is a summary diagram of our subsidiaries (Telcosur, CTG and TGSLatam) and affiliates as of December 31, 2022, including information about ownership and location:

(1) Incorporated in Argentina.

(2) Incorporated in Uruguay.

(3) Incorporated in Bolivia.

As of the date of this Annual Report, we are performing the formal steps to liquidate Emprendimientos de Gas del Sur S.A. (“EGS”).

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D. Property, Plant and Equipment

Gas Transportation

The principal components of the pipeline system we operate are as follows:

Pipelines. We render natural gas transportation service through a pipeline system that is 5,736 miles long, of which 4,775 miles operated under the License on an exclusive basis. We manage the transportation of natural gas over the remainder of the system under management agreements with the Gas Trust, which owns the remaining portions of the pipeline. The system consists primarily of large diameter, high-pressure pipelines intended for the transportation of large volumes of gas at a pressure of approximately 853-996 pound/square inch. Line valves are installed on the pipeline at regular intervals, permitting sections of the pipeline to be isolated for maintenance and repair work. Gas flow regulating and measurement facilities are also located at various points on the system to regulate gas pressures and volumes. In addition, a cathodic protection system has been installed to protect the pipeline from corrosion and significantly reduce metal loss. All of the pipelines are located underground or underwater.

Maintenance bases. Maintenance bases are located adjacent to the natural gas pipeline system in order to maintain the pipeline and related surface facilities and to handle any emergency situations which may arise. Personnel at these bases periodically examine the pipelines to verify their condition and inspect and lubricate pipeline valves. Personnel at the bases also carry out a cathodic protection system to ensure that adequate anti-corrosion systems are in place and functioning properly. Such performance also maintains and verifies the accuracy of our measurement instruments to ensure that these are functioning within appropriate industry standards and in accordance with the specifications contained in our service regulations.

Compressor plants. Compressor plants along the pipelines recompress the natural gas volumes transported in order to restore pressure to optimal operational levels, thereby ensuring maximum use of capacity as well as efficient and safe delivery. Compressor plants are spaced along the pipelines at various points (between 62 and 124 miles) depending upon certain technical characteristics of the pipelines and the required pressure for transport. Compressor plants include mainly turbine-driven compressors and, to a lesser extent, motor-driven compressors which use natural gas as fuel, together with electric power generators to supply the complementary electrical equipment (control and measurement devices, pumping, lighting, communications equipment, etc.).

We transport natural gas through four major pipeline segments: General San Martín, Neuba I Gas Pipeline, Neuba II Gas Pipeline and Loop Sur Gas Pipeline, as well as several smaller natural gas pipelines. Information with respect to certain aspects of our main natural gas pipelines as of December 31, 2022, is set out in the table below:

Major Pipeline	Length (miles)		Diameter (inches)		Maximum Pressure (pound/inch)		Compressor Units		Operative Compressor Plants		HP Output
General San Martín		2,852		24/30		853/995		59		17		512,800
Neuba I/Loop Sur		732		24/30		853		18		6		65,800
Neuba II		1,217		30/36		975/995		21		7		194,000
Other (1)		935	Various		Various			6		3		7,500
Total		5,736						104		33		780,100

(1) Includes 247 miles of transfer pipelines throughout the pipeline system, as well as the Cordillerano pipeline, with a length of 274 miles, and the Chelforó-Conesa pipeline and other minor pipelines.

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General San Martín. This pipeline was built in three stages, completed in 1965, 1973 and 1978, and transports natural gas from the extreme southern portion of Argentina to the greater Buenos Aires area in east-central Argentina. It originates in San Sebastián (Tierra del Fuego), passes through the Strait of Magellan and the Provinces of Santa Cruz, Chubut, Río Negro and Buenos Aires (including the Cerri Complex located near the city of Bahía Blanca in central Argentina), and terminates at the high pressure transmission ring around the City of Buenos Aires. The pipeline receives natural gas from the Austral basin at the extreme south in the Province of Tierra del Fuego, from the same basin further north at El Cóndor and Cerro Redondo, in the Province of Santa Cruz and from the San Jorge basin in the northern Santa Cruz and southern Chubut Provinces. The natural gas pipeline primarily serves the districts and cities of Buenos Aires, La Plata, Mar del Plata, Bahía Blanca, Puerto Madryn and Comodoro Rivadavia.  This pipeline was expanded in 2005 by the Gas Trust in order to satisfy the growing natural gas demand in the Argentine economy. This expansion resulted in the construction of 458 miles of pipeline and the installation of new compressor units. See “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Pipeline Operations—Pipeline Expansions.”

Neuba I Gas Pipeline (Sierra Barrosa-Bahía Blanca). Neuba I Gas Pipeline was built in 1970 and was expanded by us in 1996. It is one of our two main pipelines serving our principal source of gas supply, the Neuquina basin. The pipeline originates in west-central Argentina at Sierra Barrosa (Province of Neuquén), passes through the Provinces of Río Negro, La Pampa and Buenos Aires, and terminates at the Cerri Complex. This pipeline transports the natural gas received from the Neuquina basin, particularly from the Sierra Barrosa, Charco Bayo, El Medanito, Fernández Oro, Lindero Atravesado, Centenario, Río Neuquén and Loma de la Lata natural gas fields. The gas delivered from Neuba I Gas Pipeline is subsequently compressed and injected into the Loop Sur Gas Pipeline and the General San Martín pipelines for transportation north to the greater Buenos Aires area. As part of the works scheduled to be completed in the Five-Year Plan, we are executing the construction of a compressor plant in the town of Confluencia, Neuquén Province, which will allow the Neuba I Gas Pipeline to be interconnected with the Neuba II Gas Pipeline and thus grant a greater degree of flexibility to the operation of the natural gas transport system.

Loop Sur Gas Pipeline. This gas pipeline was built in 1972 as an extension of Neuba I Gas Pipeline and runs parallel to a portion of the General San Martín gas pipeline. Located in the province of Buenos Aires, it transports natural gas from the Neuba I Gas Pipeline at the Cerri Complex in Bahía Blanca and terminates at the high pressure transmission ring around Buenos Aires, which we also operate. The natural gas delivered by this gas pipeline constitutes a portion of the natural gas supply for the greater Buenos Aires area. Loop Sur Gas Pipeline is also connected to the TGN system and allows us to deliver natural gas to or receive natural gas from TGN. Such transfers occur occasionally during periods of high demand for natural gas.

Neuba II Gas Pipeline. Our newest natural gas pipeline, Neuba II Gas Pipeline, was built in 1988 and is our second pipeline serving the Neuquina basin. Neuba II Gas Pipeline was expanded four times between 1996 and 2000, and again in 2008. Neuba II Gas Pipeline begins at YPF’s Loma de la Lata gas treatment plant in the western portion of the basin and runs through the Provinces of Neuquén, Río Negro, La Pampa and Buenos Aires (through the Cerri Complex), up to its terminal station located at Ezeiza just outside of Buenos Aires. Neuba II Gas Pipeline is a principal source of natural gas for the Federal District and the greater Buenos Aires area. In 2008, this pipeline was expanded as a part of the Second Expansion, resulting in the construction of 153 miles of natural gas pipeline.

Other Pipelines. We also operate the Cordillerano natural gas pipeline, built in 1984, which receives gas from the Neuquina basin and supplies it mainly to three tourist centers in southern Argentina. In addition, we operate other minor pipelines, the high pressure transmission ring around Buenos Aires, the Chelforó-Conesa natural gas pipeline and other natural gas pipelines known as natural gas transfer pipelines.

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Additional information regarding the expansion of our gas transportation system is included in “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Pipeline Operations—Pipeline Expansions.”

Ancillary Facilities

Cathodic Protection System

Currently, we operate cathodic protection devices, which are located along our main pipelines. The objective of this system is to prevent the corrosion process. The corrosion process causes metal loss, which, depending on the severity of the damage, may cause pipeline ruptures. Cathodic protection equipment includes direct current rectifiers, and generators powered by thermic, turbine natural gas engines in locations where no electric lines are available. The system also includes an impressed current anode, which facilitates circulation of electricity through the circuit formed by the generator, the anode itself, the pipe and the land.

Measurement and Control of the Transport System

To guarantee the reliability of the facilities and optimize the operation of the transport system, it is necessary to have real-time information from the various measurement and control devices installed throughout our more than 5,769 miles of gas pipelines and 33 compressor plants.

To that effect, we have fiscal measurement stations associated with gas receptions from producer facilities and gas deliveries to our distributors or customers, in addition to the mediation equipment installed in the compressor plants to determine the volumes of pumped gas, fuel and other variables of operational interest.

All the information generated by the field devices is collected by our SCADA/EFM system, transmitted through our communications infrastructure and centralized at our headquarters. The fiscal mediation information contains volumes and quality of gas, which is collected by the SCADA/EFM system and saved in a database for further processing by other corporate systems.

In addition, the information is shared in real time with producers, distributors and ENARGAS in order to ensure the required auditability and transparency.

Natural Gas Control System

Located at our Buenos Aires headquarters, the gas control system controls scheduled gas injections and deliveries and allows us to follow gas flows in real time. Data is received from compressor stations by phone and automatically from remote terminal units (“RTUs”) installed in the receipt and delivery points equipped with the Electronic Flow Measurement (EFM) system. The information is normally collected by the supervisory control and data acquisition system (which has an ad hoc database that is updated every 30 seconds on average) and is then consolidated into other databases. In order to control gas injection and deliveries, we have developed a software system called Solicitud, Programación, Asignación y Control, which, among other things, allows us to control actual volumes and projected future injections to determine producer deviations. As part of this system, we operate meteorological equipment and receive daily weather information from various sources, which is used for the purpose of forecasting natural gas demand.

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Natural Gas Measurement

Shipped and delivered natural gas is measured through primary field facilities that are connected with RTUs. Such RTUs transmit the data to the Buenos Aires headquarters. This data is utilized to prepare reports for clients, shippers, producers and ENARGAS. Energy balances are also prepared in order to control our system efficiency.

Liquids Production and Commercialization

Our Liquids production and commercialization activities are conducted at our Cerri Complex. It is located near the city of Bahía Blanca and is connected to each of our main pipelines. The Cerri Complex consists of an ethane extraction cryogenic plant to recover ethane, LPG and natural gasoline, together with a lean oil absorption plant to recover LPG and natural gasoline (“Liquids Production and Commercialization”). The facility also includes compression, power generation and storage facilities. The Cerri Complex processing capacity is approximately 47 MMm3/d.

As part of the Cerri Complex, we also maintain at Puerto Galván a storage and loading facility for the natural gas liquids extracted at the Cerri Complex. The Cerri Complex, including the Puerto Galván facility, is currently capable of storing 68,882 short tons of liquids. See this “Item 4.—Our information—B. Business Overview—Liquids Production and Commercialization”.

Other Services

Midstream

As part of this business segment, we provide services related to natural gas including treatment, gathering and gas compression, which are rendered at two treatment plants and three gas compression plants with a total treatment capacity of 10.9 MMm3/d and a total compression capacity of 34,790 HP, respectively.

Throughout the year 2019, we successfully concluded assembly and pressurization works of an important Vaca Muerta gas pipe project that involved an aggregate investment of US$260 million and will be pivotal in the development of Vaca Muerta natural gas reserves. The execution of these works demanded great commitment from our team and compliance with all the terms agreed with our customers. The Vaca Muerta project was executed in three stages:

• Milestone 1: on April 30, 2019, we finished the construction of the southern section of the Vaca Muerta pipeline, its connection to the northern Vaca Muerta pipeline and the segment that extends from connection to the project’s conditioning plant (the construction of which is still ongoing) located in the city of Tratayén, Province of Neuquén. In addition, both an early conditioning plant (integrated to the definite conditioning plant) and the plant connection to the Neuba I Gas Pipeline began operations.

• Milestone 2: on November 3, 2019, the northern section of the Vaca Muerta pipeline began operations, connecting the Rincón la Ceniza field with the southern section of the Vaca Muerta pipeline.

• Milestone 3: on December 12, 2019, the northern section of the Vaca Muerta pipeline began operations, extending from the Los Toldos I South field to Rincón la Ceniza, connected with the section previously started. The completion of this section represented the completion of the northern section of the Vaca Muerta pipeline.

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This pipeline system goes through several hydrocarbon fields, including Bajada de Añelo, La Calera, Bandurria Sur, Fortín de Piedra, El Mangrullo, Aguada Pichana Este, Rincón la Ceniza, Los Toldos I Sur and Pampa de las Yeguas I and II. The following map shows the location of the Vaca Muerta pipeline.

With the commissioning of the conditioning train installed in the Treatyén Treatment Plant and with the completion of the work to connect said plant to the Central West Gas Pipeline, belonging to the TGN transportation system, we concluded the works that comprise the Vaca Muerta system, which has been operating since 2019, totaling an investment of US$260 million. This system, which includes two gas capture pipelines and the aforementioned plant in Tratayén will be of vital importance for the development of the Vaca Muerta natural gas reserves.

Additionally, the connection of the plan located in Tratayén to the Central West Gas Pipeline, belonging to TGN’s regulated transportation system, was completed in 2020. Moreover, in September 2020, we approved a project to expand the plant located in Tratayén. This project was commissioned in September 2021 allowing us to increase the natural gas gathering capacity in the Vaca Muerta area, and thus, increase capacity for our midstream services.

Telecommunication

We own two interconnected networks beginning in the Buenos Aires Province, which consist of (i) a flexible and modern microwave digital network with SDH technology over more than 2,858 miles, which covers the Buenos Aires–Bahía Blanca–Neuquén routes to the West and the Buenos Aires–Bahía Blanca–Comodoro Rivadavia–Río Grande routes to the South, and (ii) a dark fiber optic network of approximately 1,056 miles, which covers the La Plata–Buenos Aires–Rosario–Córdoba–San Luis–Mendoza routes. There is also a network in the Patagonia region, which consists of a “lit” fiber optic network of approximately 373 miles, which covers the Puerto Madryn–Pico Truncado route.

Environmental, Social and Governance

We are committed to managing its business and operating its facilities in compliance with the requirements of applicable legislation and the requirements to which it voluntarily adheres, satisfying the expectations of its customers and prioritizing the quality of its services, the prevention of pollution and the health and safety of its personnel and contractors, through the continuous improvement of the effectiveness of its management system.

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In this regard, during 2022 we have been working on the design of the first ESG Plan (the “ESG Plan”) in which we prioritized the thematic axes and lines of action that will guide our strategy in this area.

Environment

Our safety and environment policy establishes a commitment of compliance with the applicable legislation in environmental matters, the prevention of pollution and the continuous improvement of its Sistema de Gestión Integrado (“SGI”). This commitment extends not only to our personnel, but also to contractors who work for, or provide services to, us.

Aligned with our safety and environment policy, we implemented an environmental management system, which is integrated with quality, safety and occupational health management. The SGI is certified according to ISO 9001, ISO 14001 and OHSAS 18001. Described in this framework are the processes that make up environmental management and the responsibilities and procedures associated with each of them.

A requirement of fundamental importance for us is to guarantee compliance with applicable environmental legislation, both in regulatory matters and at the level of the different jurisdictions in which we operate. To put it into practice, we have specific procedures that establish the obligations related to specific areas and a strategy to monitor the requirements of the authorities that allow for the maintenance of the environmental permits necessary to operate. In the case of projects, the environmental impact assessment is carried out following the requirements of Argentine natural gas rule 153 (“NAG153”), and any other applicable requirement requested by each local authority. The projects are carried out following the guidelines of the environmental protection plans that arise from the evaluation process.

In the framework of strengthening sustainability management, progress was made in the first stage of our environmental improvement program (the “Environmental Improvement Program”), with the aim of managing projects that reduce the environmental impact of our operations. A series of projects focused on optimizing the measurements of environmental variables was carried out in order to have a baseline on which to set objectives associated with improvement projects, such as the calculation of the our carbon footprint, and the balance of energy efficiency in the Cerri Complex, Galván Plant and headquarters. We continue to evaluate technical alternatives with the goal of achieving “zero effluent” in the Cerri Complex.

Environmental performance is monitored through indicators that show trends in the main variables and serve as a basis to evidence the process of continuous improvement. In turn, the adequacy of the SGI in relation to the certified standards is verified through an annual program of internal audits.

We recognize that caring for the environment in the communities where we carry out our activities is essential to the strength of our business. We understand that business success is based on the ability to be recognized for operational efficiency, social responsibility and a commitment as a local company.

The Environmental Improvement Program aims to implement projects through interdisciplinary teams that allow us to know/validate the current situation of some of our environmental impacts. These validations will establish the baseline on which future improvements and investments will be calculated. The impacts considered are gaseous emissions, liquid effluents and energy consumption.

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The work methodology consists of collecting information and having reliable data that allows us to obtain gas emission inventories, liquid effluent reduction plans and measures for the most efficient use of energy.

The Environmental Improvement Program seeks to reduce negative environmental impacts and avoid lawsuits for environmental issues and non-compliance with legislation. To meet its objectives, the following projects have been developed:

• inventory of emissions;

• monitoring of emissions from the Cerri Complex;

• zero effluent in the Cerri Complex;

• diagnosis of energy efficiency in the Cerri Complex, Puerto Galván and our headquarters;

• measurement of the vents generated using seals; and

• sewage effluent treatment plant in Plaza Huincul.

In 2022 we worked on the strategic environmental plan (the “Strategic Plan”) in which we integrated the environment in all phases of the business processes, from strategic decision making to risk and opportunity management, planning, design, and execution of activities. This plan comprises the following strategic axes and action plans and programs:

• Mitigation and adaptation to climate change through the application of new technologies, reduction strategies, promotion of energy efficiency and renewable energies, as well as encouraging biodiversity conservation.

• Addressing GHG emissions management issues (emission reduction targets to 2030, assessment of the carbon neutrality gap to 2050, exploration of carbon markets, certification of the emissions inventory with ISO 14064 Standard); together with energy efficiency programs (ISO 50001 energy management system, renewable energy incorporation plan), biodiversity promotion (species inventory and protected area surveys), sustainable mobility plan and incorporation of low-emission vehicles, and environmental mitigation and environmental risk prevention measures (including climate risks).

• Proactive environmental leadership to anticipate the needs of the context, including technological innovation issues with a focus on emerging engineering solutions to analyze the applicability in tgs, and, environmental promotion and awareness programs to distinguish the environmental performance of the facilities.

• Circular economy as a model of production and consumption in our operations, to promote the efficient use of energy and natural resources, establishing activities aimed at improving their management within the framework of the circular economy.

• To promote integrated waste management in all our facilities, promoting the treatment and recovery of effluents for irrigation and water care, and the determination of the water footprint. It also includes actions to identify sustainable suppliers and generate strategies for the supply of sustainable equipment and materials.

• Each of the 3 axes of the Strategic Plan are linked to the Sustainable Development Goals (SDGs) and represent the current and future commitments of our company, recognizing the leading role of natural gas within the energy matrix towards the transition to low-carbon energies.

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Energy

With the purpose of incorporating renewable sources for our own energy consumption, we started the first experiences of incorporating photovoltaic panels in different areas and sectors to have a first diagnosis.

In 2022 we evaluated the possibility of developing corrosion protection systems using hybrid energy (solar panels and wind energy). The plan is to move forward with this issue in 2023 and progressively incorporate renewable energy sources. Regarding the incorporation of solar panels, we highlight:

- Installation of photovoltaic panels on scraper traps. To allow the opening positioning on the valves to be visualized in the SCADA, solving the difficulty that there is no availability of stable electric power required by the system.

- Incorporation of panels in Buenos Aires Metering Stations. At Nudo Las Heras Plant, an important point within the jurisdiction of Base Gutierrez, due to the crossing of the two NEUBA gas pipelines, but with difficult access, no cellular signal and power outages, solar panels were installed to maintain the energy consumption of the measuring, communication and signaling instruments of said facility. Other measurement sites where panels have been installed are Mercedes, Navarro, Saladillo, Roque Perez and General Belgrano.

New solar panels will soon be installed at the Buchanan and Ezeiza stations, which have already been acquired by tgs.

- Luminaire in emergency exits of LED plants with photovoltaic panels. In most of our facilities, the original design of the perimeter lighting did not include the emergency exit doors. For this reason, some facilities began to install luminaires at these sites to facilitate access. An example of this is Planta Compresora Olavarría and Buchanan, both in the province of Buenos Aires, which incorporated solar lighting that operates in the absence of natural light and with a motion sensor.

Emissions

In order to contribute to global efforts to reduce Greenhouse Gas (GHG) emissions, and as a midstream and natural gas transportation company, we are responsible for this finite resource. Therefore, we established our commitment to GHG emissions management.

Initially, we worked on implementing a system that favors the registration of data in each of our facilities, with the challenge that this presented due to the geographical dispersion of our company. The tool chosen for the integrated and robust management of information was SAP EHSM, and together we made progress in identifying all sources of GHG emissions from the facilities.

In 2019, we began calculating the carbon footprint of our two main businesses, natural gas transportation and Liquids production and commercialization. In parallel to the optimization work of the data collection system, we implemented tours in our facilities for the actual measurement of dry and wet seal venting by type of equipment, in order to validate the emission coefficient reported by the seal manufacturer.

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In a second instance, after knowing the main contributions to our emissions, we made investments to reduce venting, such as the stopper tool that allows us to reduce the amount of natural gas vented by pipeline maintenance. In 2021, we included the calculation of the carbon footprint for our Other Services segment following the GHG Protocol (Greenhouse Gas Protocol) guidelines.

In 2022, we worked on the company’s emissions map, in order to know our emissions profile and be able to establish goals for reducing and managing them. The following two graphs show our emissions contributions by category and methane emissions by generation source.

Biodiversity

In order to protect biodiversity in the places where tgs operates, we identified existing protected areas in the provinces reached by our businesses. In this sense, we have made progress with the design of an afforestation policy that we expect to be approved and implemented during 2023.

We are currently conducting a survey of existing trees at our facilities to determine the general condition of individuals, perform a specific characterization, verify the percentage of coverage, and identify opportunities for sustainable and conscious afforestation with native species. By 2023, the purpose is to advance with these surveys in the remaining facilities and, in parallel, to quantify the carbon sinks.  The goal is to have 100% of our facilities surveyed by 2025.

Social

Our social strategy is focused on contributing to the health and safety of people and the development of the communities where we operate, generating opportunities for professional development.

Within this framework, we develop various professional training activities for our people. With regard to occupational health, during 2022 we continued working on the development and implementation of the Emotional Wellness Program. Finally, during 2022 Occupational Health continued to focus on pandemic management by following up on confirmed and suspected cases of COVID, isolating symptomatic personnel, communicating protocols and recommendations to preserve the health of employees and ensure the continuity of our company’s operations, among other actions.

With respect to safety and hygiene, during 2022, the our Culture Program continued as a value, with the participation of more than 200 employees. The main objective of this program is to promote the Culture of Preventive Leadership for an Interdependent Organization. It is developed in a space of interaction between Environmental area referents, Facility leaders and the members of the respective work teams. This program generates actions and commitments generated from good practices by both parties that result in improvements for the processes, tasks or conditions of Safety, Hygiene, Environment and Quality, for the Facility or the participating Sector. The good practices will be chosen by the Communities, which will be applicable to the whole Company.

tgs has an Occupational Hygiene Program. It is a preventive program that studies the conditions of the work environment, identifying, evaluating and controlling physical, chemical and biological risk agents of occupational origin. It is a preventive discipline that analyzes working conditions in order to reduce the occurrence of occupational diseases.

Within this program, the agents within the respective work environments are identified and the concentrations and exposures of workers to them are determined. Then, a risk assessment is carried out, proposing and applying preventive measures that eliminate or minimize exposure, determining collective conclusions for the improvement of the process or the workplace.

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Governance

In May 2022, we presented our Sustainability Report 2021, which brings together the environmental, social and economic indicators of its management, based on the prioritization of the Sustainable Development Goals (SDGs), in line with the principles established by the United Nations. The 2021 Sustainability Report uses the sustainability guidelines of reference worldwide, such as the Global Reporting Initiative (GRI) and the Sustainability Accounting Standards Board (SASB).

On the other hand, in 2022 risk management was included as a key issue in the ESG Strategic Plan defined by the Company, aiming to implement the respective action plan during 2023.

Information Technology

We rely on our information technology systems and automated machinery to effectively manage our production processes and operate our business. As with other companies, our information technology systems may be vulnerable to damage or interruption from cyber-attacks and other security breaches.

We follow the Cybersecurity Framework developed by U.S. Department of Commerce’s National Institute of Standards and Technology (“NIST”). We assess the maturity level tested against the latest cybersecurity trends and disclosure research. Our framework follows NIST’s five core functions to help us identify cybersecurity compliance gaps and requirements.

We depend on digital technology, including information systems to process financial and operating data. Our business has become dependent on digital technologies to conduct day-to-day operations and we may be subject to cyberattacks or other risks related to new technologies.

Insurance

We maintain insurance, subject to deductibles, against third-party liability for damage to all of our facilities used in the Liquids and Other Services business segments and our pipeline assets that pass under rivers or other bodies of water and the Strait of Magellan and business interruption. We believe this coverage is consistent with standards for international natural gas transportation companies. The terms of the policies related to the regulated assets have been approved by ENARGAS. In addition, we have obtained insurance coverage for our directors and officers pursuant to a standard D&O insurance. For additional information, see “Item 3. Key Information.—D. Risk Factors.—Risks Relating to Our Business—Our insurance policies may not fully cover damage or we may not be able to obtain insurance against certain risks.”

Item 4A. Unresolved Staff Comments

We do not have any unresolved staff comments.

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Item 5. Operating and Financial Review and Prospects

A. Operating Results

The following Operating and Financial Review and Prospects should be read in conjunction with our Financial Statements included elsewhere herein.

This Operating and Financial Review and Prospects discussion contains forward-looking statements that involve certain risks, uncertainties and assumptions. These forward-looking statements can be identified by the use of forward-looking terminology such as “may,” “will,” “will likely result,” “intend,” “projection,” “should,” “believe,” “expect,” “anticipate,” “estimate,” “continue,” “plan” or other similar words. Our actual results may differ materially from those identified in these forward-looking statements. For more information on forward-looking statements, see “Cautionary Statement Regarding Forward-Looking Statements.” In addition, for a discussion of important factors, including, but not limited to, the pesification of our tariffs and other factors that could cause actual results to differ materially from the results referred to in the forward-looking statements, see “Item 3. Key Information—D. Risk Factors.”

For purposes of the following discussion and analysis, unless otherwise specified, references to fiscal years 2022, 2021 and 2020 relate to the fiscal years ended December 31, 2022, 2021 and 2020, respectively.

We maintain our accounting books and records in pesos. Our Financial Statements as of December 31, 2022 and 2021 and for the years ended December 31, 2022, 2021 and 2020 have been prepared in accordance with the accounting policies based on IFRS as issued by the IASB.

Our management considers that there is sufficient evidence to conclude that Argentina is a hyperinflationary economy in terms of IAS 29, effective as of July 1, 2018. As a result, (i) our audited consolidated statements of financial position as of December 31, 2022, and our audited consolidated statements of comprehensive income, changes in equity and cash flows, and the related explanatory notes for the year ended December 31, 2022, included elsewhere in this Annual Report have been prepared using hyperinflation accounting in accordance with IAS 29, and (ii) our audited consolidated statements of financial position as of December 31, 2021, and our audited consolidated statements of comprehensive income, changes in equity and cash flows, and the related explanatory notes for the years ended December 31, 2021 and 2020, included elsewhere in this Annual Report have been restated to Current Currency in accordance with IAS 29 for comparative purposes. Thus, the Financial Statements and the financial information included in this Annual Report for all the periods reported are presented on the basis of constant pesos as of December 31, 2022.

For information relating to the presentation of financial information, see “Presentation of Financial and Other Information.”

Critical Accounting Policies

Critical accounting policies are those that are most important to the portrayal of our financial condition, results of operations and cash flows, and require management to make difficult, subjective or complex judgments and estimates about matters that are inherently uncertain. In connection with the preparation of our Financial Statements included in this Annual Report, we have relied on assumptions derived from historical experience and various other factors that we deemed reasonable and relevant. Although we review these assumptions in the ordinary course of our business at the end of each reporting period, the presentation of our financial condition and results of operations often requires management to make judgments regarding the effects of matters that are inherently uncertain. Actual results may differ from those estimated as a result of these different assumptions.

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We have described each of the following critical accounting policies in order to provide an understanding about how our management forms judgments and views with respect to such policies and estimates:

• impairment of property, plant and equipment (“PPE”);

• provisions for legal claims and others; and

• income tax – deferred tax assets and tax credits.

For additional information regarding our Critical Accounting policies, see Note 5 to our Financial Statements.

Factors Affecting Our Consolidated Results of Operations

Year to year fluctuations in our net income are a result of a combination of factors, including primarily:

• the volume of Liquids;

• changes in international prices of LPG and natural gasoline;

• regulation affecting our liquids business, including Law No. 26,020 (which requires us to meet domestic demand before exporting LPG);

• changes in the input costs related to the liquids production and commercialization segment, including the Gas Charge Resolutions;

• the availability of natural gas and its richness;

• fluctuation in the peso/U.S. dollar exchange rate;

• the tariffs we are permitted to charge in our Natural Gas Transportation business segment;

• local inflation and its impact on costs expressed in pesos; and

• other changes in laws or regulations affecting our operations, including tax matters.

Sources of revenue

Natural gas transportation

Our Natural Gas Transportation operations derive revenues from the sale of transportation capacity to customers. The applicable rates derive from the tariff tables published by ENARGAS by remained unchanged between April 2019 and March 2022.

For additional information see “Item 4. Our Information—B. Business Overview—Natural Gas Transportation.”

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Production and commercialization of Liquids

Our production and commercialization of liquids operations generate revenues from the sale of propane, butane, ethane and natural gasoline, in the local and international markets. Regarding propane and butane, sold in the local market we sell our production mainly under the programs stated by the Government.

We also provide certain related services comprising reception, storage and dispatch of the liquids from the facilities located in Puerto Galván.

For additional information see “Item 4. Our Information—B. Business Overview—Liquids Production and Commercialization.”

Other services

The services included in the Other Services segment consist mainly in: (i) treatment, removal of impurities and natural gas compression, including the collection and transport of natural gas, (ii) inspection and maintenance of pipelines and compressor plants, (iii) services of steam generation for electricity production and management services for expansion works and steam generation for the production of electricity, and (iv) natural gas transportation and conditioning services in Vaca Muerta.

 

Telecommunications

Our telecommunications services are derived from the sale of our capacity to customers.

Macroeconomic conditions and inflation

As we are an Argentine corporation (sociedad anónima) and all of our operations and assets are located in Argentina, we are affected by general economic conditions in the country, such as demand for natural gas, inflation and fluctuations in currency exchange rates. Moreover, as a provider of a regulated service and producer of hydrocarbons, the prices of our services and products are subject to significant intervention by the Government. In particular, these factors affect our operating costs and revenues.

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For the year ended December 31, 2022, 25% and 63% of our revenues were attributable to our Liquids Production and Commercialization segment and to our Natural Gas Transportation business segment, respectively.

The following table sets forth, for the years indicated, the variation of key macroeconomic indicators in Argentina during the years specified below, as reported by official sources.

	2022		2021		2020
WPI (in %)		94.8		51.3		35.4
CPI (in %)		94.8		50.9		36.1
Devaluation of pesos vs. dollar (in %)		72.5		22.1		40.5
Real GDP (pesos of 2004) (% change)		5.9		10.4		(9.9	)
Industrial production (% change)		4.5		10.4		5.3
Transportation services tariffs increase(1)		60.0		—		—

Source: INDEC, Banco Nación, Statistical Agencies for the Province of San Luis and the City of Buenos Aires.

(1) Tariff increase granted since March 2022.

Argentina has faced and continues to face inflationary pressures. During periods of high inflation, effective wages and salaries tend to fall and consumers adjust their consumption patterns to eliminate unnecessary expenses. The increase in inflationary risk may erode macroeconomic growth and further limit the availability of financing, causing a negative impact on our operations. Inflation increases also have a negative impact on our cost of sales, selling expenses and administrative expenses. We cannot give any assurance that increased costs as a result of inflation will be offset in whole or in part with increases in prices of our products and services.

During the past five years CPI, measured by INDEC, has remained high in Argentina. During 2019, the Argentine government adopted measures intended to control inflation, which contributed to a deep recession. Despite these efforts, inflation in Argentina continued to rise, particularly since 2020 and because of the measures taken by the government to contain the population during the COVID. Considering the CPI, inflation was 94.8%, 50.9%, 36.1%, 53.8% and 47.6% in the years ended December 31, 2022, 2021, 2020, 2019 and 2018, respectively.

In February 2023, the INDEC published the CPI which rose to 6.6%, 102.3% when measured year-on-year.

Unless we can implement measures that allow us to mitigate the impact of inflation on our costs and increasing the efficiency, inflation may materially adversely affect our financial condition and results of operations.

In January 2007, the INDEC modified its methodology for calculating the CPI in order to reflect the CPI for the greater Buenos Aires Area (CPI-GBA). Some private analysts have suggested that the change was driven by Argentina’s policy to control inflation and reduce payments on its inflation-linked bonds and have materially disagreed, and continue to disagree, with INDEC’s official inflation data (as well as other economic data affected by inflation data). In January 2014, the Government established the IPCNu, which more broadly reflects consumer prices by considering price information from the 23 provinces of the country and the City of Buenos Aires. The methodological and geographic differences in the calculation of the CPI-GBA and the IPCNu caused the Government to decide to discontinue the publication of the IPCNu.

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On January 7, 2016, the new leadership of the INDEC declared a “national statistical emergency” and implemented several reforms to reorganize the INDEC. As a result, the INDEC did not publish CPI data until June 2016, with information from April 2016. During the implementation of these reforms, the INDEC used the figures for CPI and other official statistics published by the Province of San Luis and the Autonomous City of Buenos Aires. The CPI for the first four months of 2016 and November and December 2015 has not been published. Further, there are no communications from the INDEC expressing their intention to recalculate CPI for those months.

IAS 29 requires that the financial statements of an entity whose functional currency is that of a hyperinflationary economy, regardless of whether they are based on the historical cost method or the current cost method, be expressed in terms of the current unit of measurement at the reporting date of the reporting period. IAS standard lists a series of factors that should be considered in determining whether an economy is hyperinflationary, including whether the cumulative rate of inflation over three years’ approaches or exceeds 100%.

In order to evaluate the aforementioned quantitative condition, and also to restate the financial statements, the CNV has established that the series of indexes to be used for the application of IAS 29 is determined by the FACPCE. This series of indexes combines the CPI as of January 2017 (base month: December 2016) with the WPI, both published by the INDEC until that date, computing for the months of November and December 2015, for which there is no information from the INDEC on the evolution of the WPI, the variation in the CPI of the Autonomous City of Buenos Aires.

Since June 2018, the International Practices Task Force of the Center for Quality, which monitors “highly inflationary countries”, categorized Argentina as a hyperinflationary country.

The restatement method of IAS 29 provides that monetary assets and liabilities (those with a fixed nominal value in local currency) must not be restated since they are already expressed in the current unit of measurement at the end of the reporting period. In an inflationary period, maintaining monetary assets generates loss of purchasing power and maintaining monetary liabilities generates a gain in purchasing power; provided that such items are not subject to an adjustment mechanism that compensates to some extent for these effects. The monetary loss or gain is included in the result of the period reported, revealing this information in a separate line item.

Assets and liabilities subject to adjustments based on specific inflation agreements must be adjusted in accordance with such agreements. The non-monetary items measured at their current values at the end of the reporting period, such as the net realization value or others, do not need to be restated. The remaining non-monetary assets and liabilities must be (i) restated by applying a general price index and (ii) expressed in the measuring unit (the hyperinflationary currency) current at the end of the reporting period. Any restated non-monetary asset amount does not exceed its recoverable amount.

As of the IAS 29 transition date (January 1, 2016), we applied the following rules to express the shareholders’ equity accounts in the currency unit as of December 31, 2022:

• The components of the capital stock were restated from the dates they were contributed;

• Reserved earnings were maintained at the date of transition at their nominal value (legal amount without restatement);

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• The restated unallocated results were determined by the difference between the net assets restated at the transition date and the rest of the initial equity components expressed as indicated in the preceding paragraphs; and

• After the restatement at the transition date, all the components of the equity were restated by applying the general price index from the beginning of the period, and each variation of those components was restated from the date of contribution or from the moment in which the variation is added by any other means.

Revenues and expenses (including interest and foreign exchange differences) are restated from the date of their booking, except for those income statement items that reflect or include in their determination the consumption of assets measured in purchasing power of a date before the consumption booked, which are restated based on the date of origin of the asset to which the item is related (for example, depreciation and other consumption of assets valued at historical cost); and also those results that arise from comparing two measurements expressed in purchasing power currency of different dates, for which it is necessary to identify the amounts compared, restate them separately, and make the comparison, but with the amounts already restated.

Because Natural Gas Transportation business segment sales represented 25% of our total revenues during the year 2022, and are denominated in pesos, any further increase in the rate of inflation not accompanied by a parallel increase in our tariffs would decrease our revenues in real terms and adversely affect our results of operations.

For additional information regarding the impact of the application of IAS 29, see Note 4.d to our Financial Statements included elsewhere in this Annual Report.

In addition, inflation may negatively affect income tax payable. For example, under hyperinflationary contexts, the existence of higher monetary liabilities over monetary assets will mean an increase in income tax payable. Act 27,468 substituted the WPI for the CPI for the calculation of the indexation adjustments for tax purposes, and it modified the standards for triggering the tax indexation procedure.

In order to calculate income tax payable, since the amendment of Law No. 27,541, one-sixth of the income tax inflation adjustment shall be computed in each fiscal year, and the remaining five-sixths shall be computed in equal parts, in the five immediately following fiscal years.

Since December 31, 2019, the accumulated variation of the CPI exceeds the threshold set for the application of the income tax inflation adjustment. For the year 2022, we recorded a loss of Ps. 3,782 million in our Income Tax line item of our Statement of Comprehensive Income regarding the application of the above-mentioned tax inflation adjustment.

Economic situation and outlook

We operate in a complex economic context whose main variables have recently had strong volatility. According to the WEO issued by the IMF, world GDP is expected to have grown by 3.4% in 2022 and to grow by 2.9% in 2023. These weaker growth estimates since 2001, except for the financial crisis and the deepest stage of COVID, signify a slowdown in developed economies, the impact of measures taken to mitigate the effect of rising global inflation and the restrictions imposed by China to maintain its zero COVID policy.

Inflation, the highest in recent decades, has been the most impactful economic variable in 2022. It has been driven by supply chain restrictions and the conflict between Ukraine and Russia. The most affected goods were those linked to energy, raw materials, and food. However, the rapid increase in demand and employment in countries such as the United States has also put upward pressure on prices.

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This global macroeconomic backdrop has been particularly challenging for emerging markets and developing economies. The appreciation of the U.S. dollar added pressure to domestic prices and rising interest rates to the external financing accessed by these countries. This and capital outflows have caused these countries to have problems refinancing their indebtedness.

During the first quarter of 2022, Argentina and the IMF reached an agreement where fiscal and monetary goals were established, and a refinancing of maturities was obtained. However, the inflationary inertia continues, and as of December 31, 2022, year-on-year inflation reached 94.8%.

The main macroeconomic issues and the measures adopted by the Government are described below:

Economic activity, poverty and unemployment

In recent years, the Argentine economy suffered a significant impact from the crisis generated by COVID to the difficult moment that the international economy is experiencing due to high inflation and the conflict between Russia and Ukraine.

In this sense, after the abrupt economic slowdown produced in 2020 as a result of the sanitary measures imposed, the economy has begun a path of recovery in 2021, reaching an increase of 10.4% in the Monthly Estimator of Economic Activity (“EMAE”). This trend was reduced during 2022, showing that indicator a positive variation, as of November of that year, of 2.6% year-on-year. Recent estimates predict that given the volatile Argentine and international situation, economic growth would slow down during 2023.

Additionally, the unemployment presented a rate of 7.1% for the third quarter of 2022, according to the latest information provided by INDEC.

Likewise, the pandemic has had a profound initial impact on the lowest-income sectors. The latest official statistical data available from INDEC corresponds to the first semester of 2022 and indicates that in that period poverty reached 36.5%.

Fiscal imbalance

The primary fiscal deficit continued to be high, amounting in 2022 to 2.4% of the Gross Domestic Product (“GDP”). For its part, the financial deficit amounted to 4.2% of GDP. The reduction compared to 2021 was mainly due to the reorganization of the fiscal accounts carried out in order to meet the goals agreed with the IMF in the Extended Facilities Program.

Tariff policy

Reducing the fiscal deficit is one of the central issues within the framework of the principle of agreement with the IMF, and a large part of the deficit is explained by the growth of subsidies that cover the delay with tariffs. Public services tariffs have been virtually (in some cases completely and in others partially) frozen for almost 24 months.

During 2022, public service companies only received temporary rate increases since the RTI renegotiation process has not been completed. In fact, towards the end of 2022, the Government extended its completion period until the end of 2023.

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Likewise, in order to encourage production, to reduce the impact on certain types of natural gas consumers and to reduce the subsidies paid to natural gas producers, as from November 2020, the Plan for the Promotion of Argentine Natural Gas Production - Supply and Demand Scheme 2020-2024 was established through Decree No. 892/2020 (the “Gas.Ar Plan”).

In addition, the conflict between Russia and Ukraine has been a major factor of global destabilization that led to a significant increase in the price of commodities, including natural gas. In this context, at the end of 2022, the Argentine Government announced an agreement for the supply of natural gas from Bolivia during the winter period. This new agreement includes lower quantities of natural gas provided by Bolivia. Notwithstanding, the increase in natural gas prices could negatively affect Argentina’s current fiscal imbalance. Also, the availability and price of natural gas are key factors for the normal development of the Cerri Complex’s Liquids production activities.

Monetary imbalance and inflation

The country faces certain monetary imbalances aggravated by the high level of monetary issue as a result of the assistance measures adopted by the Government, thus pressing the international reserves of the BCRA. The fall in the BCRA’s international reserves, accompanied by an increase in its monetary liabilities, has led to a tightening of the foreign exchange regulations that imposed restrictions on the accumulation and consumption of foreign currency and payments abroad, which in turn generated a significant gap between the official exchange rate and that of freer trading venues. For further information, see “Note 16 - Financial Risk Management” to our Financial Statements included elsewhere in this Annual Report.

In order to deal with this situation, the Government has adopted several measures, among which we can mention: maximum price plans for certain food products, limitations to increases in utility tariffs and a limited exchange rate devaluation policy.

According to the latest Survey of Market Expectations carried out by the BCRA corresponding to December 2022, the median resulting from the estimates made by the 37 participants of the REM, showed an expected inflation of 98.4% for 2023.

Public debt

In 2022, an extremely important milestone was achieved, which was the agreement reached with the IMF for a new Extended Facilities Program. With a duration of 30 months, disbursements are made over 10 years, with four and a half years of grace, this program allows the country to postpone its maturities with the agency and strengthen its reserves in the short term. Among the commitments assumed is gradual fiscal consolidation -reaching equilibrium in 2025- together with the reduction of monetary financing of the deficit and the accumulation of reserves to gain some freedom in monetary policy.

Currency Exchange market

The low level of reserves in the BCRA has led the National Government to maintain a very restrictive exchange control for the purchase of foreign currency in the MULC, in which the price of the U.S. dollar on December 31, 2022, was $176.96 (buyer) and $177.16 (seller), representing an increase of approximately 72%, well below inflation as measured by the CPI. However, as of December 31, 2022, the gap with respect to the alternative quotations of the U.S. dollar obtained in the market was close to 100%.

Since the primary elections that took place in September 2021, the BCRA had to tighten the exchange rate clamp to try to stop the leak of foreign currency, establishing, among other measures, greater restrictions on access to the MULC for imports. For further information, see “Note 16.1.1. – Risk associated with exchange rate” to our Financial Statements included elsewhere in this Annual Report.

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The current economic context, and in particular, the exchange market generates expectations that the local currency will continue to devaluate, being a relevant aspect the speed with which this issue may develop in the next months, as well as other restrictions and/or developments in the exchange market with effects on different aspects of the economic activity, such as foreign trade and others.

Our management permanently monitors the evolution of the situations affecting its business, in order to determine the possible actions to be taken and identify the eventual impacts on its financial position and the results of its operations. The Company’s financial statements should be read considering these circumstances.

While our business continued growing in 2022, our operating results, financial condition and cash flows remain vulnerable to fluctuations in the Argentine economy. See “Item 3. Key Information—D. Risk Factors—Risks Relating to Argentina.”

Management review of 2022 and outlook

Review

During 2022, our financial position has remained stable and, as discussed in “B. Liquidity and capital resources”, cash flow from operations has been sufficient to finance our investment plans and capex for 2022. As of December 31, 2022 there have not been material changes to our Statement of Financial Position compared to December 31, 2021.

Our revenues were negatively impacted by the evolution of inflation and the lack of tariff adjustment of the natural gas transportation segment, among others. For further information, see “Discussion of results of operations for the years ended December 31, 2022 and 2021” below.

On August 16, 2022, RG No. 5268/2022 established by the AFIP, set forth a new and additional extraordinary advance payment of income tax on account to the general advance payment regime. For fiscal year 2022, we paid to the AFIP Ps. 3,368 million for this concept. During fiscal year 2022, we have made a total income tax advance payment of Ps. 25,688 million compared to Ps. 8,360 million in fiscal year 2021.

During 2022 we have not incurred in significant new indebtedness, and we have allocated our short-term investment in financial instruments to protect our financial position from inflation and devaluation. However, we cannot assure that the evolution of inflation and other macroeconomic variables will not have an adverse effect on our financial position and results of operations. For further information, see “Item 3. Key Information—D. Risk Factors”.

Outlook and other material events that may impact the our financial condition

In 2023, we expect to continue negotiating with ENARGAS the tariffs adjustments under the RTI process that will allow us to obtain a fair and reasonable tariff.

Regarding the Liquids segment, the current conflict between Russia and Ukraine, together with the global inflationary context and increase in NGL costs, are expected to increase the volatility in international reference prices. Additionally, as a result of the increase in sea freight costs, the prices at which our products are exported are foreseen to be subject to reduced margins, which could negatively impact the operating margins of the Liquids business segment.

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We are expecting inflationary cost to continue at an elevated level throughout 2023 across our business.

To prepare for our long-term growth, we expect to continue focusing on Vaca Muerta and exploring alternatives that will allow us to profit from our investments and to increase our portfolio of services.

New accounting pronouncements adopted after January 1, 2022, and pronouncements not yet effective as of December 31, 2022

For more information, see Note 4.a Critical accounting policies to our Financial Statements.

Discussion of Results of Operations for the Years Ended December 31, 2022 and 2021

The following table presents a summary of our consolidated results of operations for the years ended December 31, 2022 and 2021, stated in millions of pesos, and the increase or decrease and percentage of change between the periods presented:

	Year ended December 31,
	2022			2021			Variation			Percentage of change
	(in millions of pesos)
Revenues		164,525			173,320			(8,795	)		(5.1	)
Net costs of sales		(96,042	)		(92,843	)		(3,199	)		3.4
Gross profit		68,483			80,477			(11,994	)		(14.9	)
Administrative and selling expenses		(15,958	)		(14,336	)		(1,622	)		11.3
Other operating results		(76	)		251			(327	)		(130.3	)
Operating profit		52,449			66,392			(13,943	)		(21.0	)
Net financial results		(3,160	)		(850	)		(2,310	)		271.8
Share of profit from associates		90			41			49			119.5
Income tax expense		(17,061	)		(24,811	)		7,750			(31.2	)
Total comprehensive income for the year		32,318			40,772			(8,454	)		(20.7	)

Year 2022 Compared to Year 2021

Total comprehensive income

For the year ended December 31, 2022, we reported a total net income and a total comprehensive income of Ps. 32,318 million, which represents a Ps. 8,454 million decrease compared to the total net income and total comprehensive income of Ps. 40,772 million reported in 2021.

The material factors affecting total comprehensive income were as follows:

• Net revenues to third-parties reached Ps. 164,525 million in 2022, which represents a Ps. 8,795 million decrease compared to the 2021 fiscal year. This decrease was mainly due to the reduction in the Natural Gas Transportation and Liquids Production and Commercialization business segments revenues of Ps. 7,086 million and Ps. 4,345 million, respectively.

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• Net cost of sales, including depreciation of fixed assets, reached Ps. 96,042 million in 2022, which represents a Ps. 3,199 million increase compared to the 2021 fiscal year. This increase was mainly due to: (i) the growth in the cost of natural gas processed in the Cerri Complex (mainly due an increase in price, measured in constant pesos) by Ps. 3,131 million, (ii) labor costs by Ps. 1,259 million and (iii) depreciations by Ps. 931 million. These effects were partially offset by a decrease in the repair and maintenance costs by Ps. 1,348 million and third parties services by Ps. 676 million.

• Administrative and selling expenses were Ps. 15,958 million in 2022, which represents a Ps. 1,622 million increase compared to the 2021 fiscal year. This increase was mainly due to higher: (i) labor costs by Ps. 590 million, (ii) tax on export and taxes by Ps.697 million, (iii) services received from third parties by Ps. 290 million and a lower charge for doubtful accounts by Ps. 130 million. These effects were partially offset, principally, by a decrease in turnover tax of Ps. 222 million.

During 2022, subsidies increased by Ps.1,341 million, this mainly driven by the increase in international prices and the lack of updating of the prices paid in the local market. For more information see “Item 4. Our Information—B. Business Overview—Liquids Production and Commercialization.”

Net cost of sales for the years ended on December 31, 2022 and 2021, represented 58.4% and 53.6%, respectively, of net revenues reported in the corresponding year.

Administrative and selling expenses for the years ended on December 31, 2022 and 2021, represented 9.7% and 8.3%, respectively, of net revenues reported in the corresponding year.

See. “—Analysis of Operating Profit by Business Segment for the Years Ended December 31, 2021 and 2020.”

Share of profit from associates

For the year ended December 31, 2022, we recorded a profit from our investment in associates of Ps.90 million, compared to the profit of Ps.41 million recorded in 2021.

Net Financial Results

In accordance with IAS 29 we presented the financial results in gross terms considering the effects of the change in the currency purchasing power in a single separate line (“Gain on monetary position”). Gains and losses from monetary positions represent the effects of inflation on our monetary liabilities and assets, respectively.

Net financial results for the years ended December 31, 2022 and 2021, are as follows:

	Year ended December 31,
	2022			2021
	(in millions of pesos)
Financial income
Interest income		1,834			1,543
Foreign exchange gain		27,942			11,844
Subtotal		29,777			13,387
Financial expenses
Interest expense		(6,798	)		(8,703	)
Foreign exchange loss		(52,106	)		(24,239	)
Subtotal		(58,904	)		(32,943	)
Other financial results
Notes repurchase results		(1,030	)		(807	)
Fair value (loss) / gain on financial instruments through profit and loss		(128	)		(157	)
Derivative financial instruments results		24,128			2.320
Other financial charges		(771	)		(961	)
Subtotal		22,200			395
Gain on monetary position		3,768			18,311
Total		(3,160	)		(850	)

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In accordance with the provisions of IAS 29, we opted to present the gain on the monetary position in a single line included in the financial results. This presentation implies that the nominal magnitudes of the financial results have been adjusted for inflation. The real magnitudes of financial results are different from the components of financial results presented above.

For fiscal year 2022, the net financial loss increased by Ps. 2,310 million compared to the 2021 fiscal year. This negative variation is mainly due to the lower gain on net monetary position (due to the lower net monetary liability position during 2022) and the higher negative net foreign exchange difference. These effects were partially offset by the gain recognized in 2022 for generated by financial assets measured at fair value and higher interest.

The selling peso/U.S. dollar ended exchange rate closed at a value of Ps. 177.96 per U.S. dollar as of December 31, 2022, representing an increase of 72% (or Ps. 74.44 per U.S. dollar) compared to the exchange rate observed at the closing of 2021. As of December 31, 2021, said rate had increased by 22% (or Ps. 18.57 for each U.S. dollar) regarding its quote at the closing of the 2020. For its part, our net liability position in U.S. dollars has been reduced in 2022.

Income tax

Income tax for fiscal year 2022 was an expense of Ps. 17,061 million, compared to the expense of Ps. 24,811 million in fiscal year 2021. The lower income tax charge was primarily due to the decrease in taxable income in fiscal year 2022.

The following table sets forth revenues and operating income for each of our business segments for the years ended December 31, 2022 and 2021:

	Year ended December 31,						Year ended December 31, 2022 compared to year ended December 31, 2021
	2022			2021			Variation			Percentage Change
	(in millions of pesos)
Natural Gas Transportation(1)
Revenues from sales		41,808			49,484			(7,676	)		(15.5	)
Net cost of sales		(29,357	)		(30,399	)		1,041			(3.4	)
Gross profit		12,451			19,085			(6,634	)		(34.8	)
Administrative and selling expenses		(7,250	)		(7,174	)		(76	)		1.1
Other operating expense		(180	)		(397	)		(216	)		(54.4	)
Operating profit		5,021			11,514			(6,494	)		(56.4	)
Liquids Production and Commercialization
Revenues from sales		104,215			108,560			(4,345	)		(4.0	)
Net cost of sales		(58,785	)		(56,281	)		(2,504	)		4.4
Gross profit		45,430			52,279			(6,849	)		(13,1	)
Administrative and selling expenses		(6,567	)		(5,553	)		(1,014	)		18.3
Other operating income		38			627			(589	)		(93.9	)
Operating profit		38,901			47,353			(8,452	)		(17.8	)
Other Services
Revenues from sales		18,747			16,138			2,609			16.2
Net cost of sales		(8,408	)		(7,295	)		(1,113	)		15.3
Gross profit		10,339			8,843			1,496			16.9
Administrative and selling expenses		(1,964	)		(1,476	)		(488	)		33.1
Other operating (expense) / income		66			20			46			227.9
Operating profit		8,441			7,387			1,054			14.3
Telecommunications
Revenues from sales		919			892			27			3.0
Net cost of sales		(657	)		(623	)		(33	)		5.4
Gross profit		263			269			(6	)		(2.4	)
Administrative and selling expenses		(177	)		(132	)		(44	)		33.6
Other operating expense		-			1			(-	)		(48.7	)
Operating profit		86			138			(51	)		(37.3	)

(1) Includes intersegment revenues of Ps. 1,165 million and Ps. 1,754 million for the fiscal years 2022 and 2021, respectively.

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Regulated Natural Gas Transportation Segment

The Natural Gas Transportation business segment represented 25.4% and 28.5% of our total revenues during the years 2022 and 2021, respectively. Natural Gas Transportation revenues are derived mainly from firm contracts, under which pipeline capacity is reserved and paid for regardless of actual usage by the shipper. We also provide interruptible natural gas transportation services subject to availability of the pipeline capacity. In addition, we render operation and maintenance services for the Natural Gas Transportation facilities, which belong to certain gas trusts created by the Government to expand the capacity of the Argentine natural gas transportation pipeline system. This business segment is subject to ENARGAS regulation.

For additional information regarding the history of our discussions with various governmental authorities in relation to the adjustment of our gas transportation tariffs see “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Regulatory Framework.”

• During 2022, the Natural Gas Transportation business segment recorded an operating profit of Ps. 5,021 million, compared to a Ps.11,514 million profit recorded in 2021. The main factors that affected the results of operations of this segment compared to 2022 are the following:

• Revenues from the Natural Gas Transportation business segment decreased by Ps.7,676 million for the year 2022 compared to 2021;

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• During 2022, we had only received a nominal tariff increase of 60% as of March 1, 2022 while annual inflation was 94.8%.

• Revenues related to natural gas firm transportation contracts for the year ended December 31, 2022, decreased by Ps.4,822 million for the year 2022 compared to 2021, as we had only received a nominal tariff increases of 60% as of March 1, 2022, while the cumulative inflation rate for the Year 2022 was 94.8%. See “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Regulatory Framework—Regulation of Transportation Rates—Actual Rates” for additional information;

• Revenues related to interruptible natural gas transportation service decreased by Ps. 1,994 million for the year 2022 compared to 2021. The decrease mainly resulted from tariff increase discussed above, partially offset by higher volumes dispatched;

• Revenues relating to the CAU decreased by Ps. 270 million for the year 2022 compared to 2021 primarily as a result of the same tariff effect. The value of the CAU is much lower than the transportation tariff we are permitted to charge for our natural gas transportation services, because we were not required to make any investment in the construction and expansion of the assets to which the CAU relates. See “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Pipeline Operations—Pipeline Expansions” for additional information regarding the CAU;

• Costs of sales and administrative and selling expenses for the year ended December 31, 2022 decreased by Ps. 965 million, from Ps. 37,573 million to Ps. 36,607 million, as compared to the year ended December 31, 2021. This decrease was mainly attributable to lower PPE maintenance expenses of Ps. 1,487 million, as during 2022 we performed less repairs, technical operator assistance fees of Ps. 463 million and lower turnover tax by Ps. 488 million. These effects were partially offset, principally, by higher: (i) labor costs of Ps. 543 million, (ii) depreciation of Ps. 621 million;

• Other operating expenses decreased by Ps. 216 million for the year 2022 compared to 2021, primarily as a result of higher provision for contingencies.

The Government has not issued the necessary resolutions to carry out the RTI process according to the Solidarity Law, but we have received a 60% transitory tariff increase effective since March 1, 2022.

On March 15, 2023, ENARGAS submitted to us a proposal for an addendum to the RTI. The proposal includes a transitional tariff increase of 95%. As of today, the addendum has not yet been implemented.

Liquids Production and Commercialization Segment

Unlike the Natural Gas Transportation segment, revenues of the Liquids Production and Commercialization segment are not subject to full regulation by ENARGAS and the Ministry of Energy. However, in recent years, the Government has enacted a number of laws and regulations that have limited our ability to receive the full international market prices for all of the liquids that the Cerri Complex produces. In addition, ENARGAS has the ability to redirect the volumes of natural gas in the system to cover certain uses and that may result in lower volumes of natural gas to be processed in the Cerri Complex. See “Item 4. Our Information—B. Business Overview—Liquids Production and Commercialization—Regulation” for more information.

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The Liquids Production and Commercialization segment represented 63.3% and 62.6% of our total revenues during the years ended December 31, 2022 and 2021, respectively. Liquids Production and Commercialization activities are conducted at the Cerri Complex, which is located near Bahía Blanca and is connected to each of our main pipelines. At the Cerri Complex, we recover ethane, LPG and natural gasoline for our own account, on behalf of our customers and on a fee basis, collecting a commission for the extracted Liquids delivered to our customers.

For the fiscal years 2022 and 2021, all of our sales were made for our own account.

All ethane produced by our Liquids segment in the years ended December 31, 2022 and 2021 was sold locally to PBB.

Our ethane sales for the years 2022 and 2021 represented 24.6% of our Liquids Production and Commercialization net revenues.

In 2022, we sold 50.9% of our production of LPG in the local market to LPG marketers, compared to 55.1% in 2021, with the remainder exported to LPG traders. In addition, all natural gasoline produced during 2022 and 2021 was exported. For more information about these contracts, see “Item 4. Our Information—B. Business Overview—Liquids Production and Commercialization.”

The total annual sales for the Cerri Complex for 2022 and 2021 in tons were as follows:

	Years ended December 31,				Year ended December 31, 2022 compared to year ended December 31, 2021
	(volumes in tons)				(volumes in tons)
	2022		2021		Increase/ (Decrease)			Percentage Change
Local Market
Ethane		329,232		353,078		(23,846	)		(6.7	)
Propane		215,753		238,284		(22,531	)		(9.4	)
Butane		185,472		181,952		3,520			1.9
Subtotal		730,457		773,314		(42,857	)		(5.5	)
Exports
Propane		194,810		144,801		50,009			34.5
Butane		78,460		85,627		(7,167	)		(8.4	)
Natural Gasoline		125,277		115,677		9,600			8.3
Subtotal		398,547		346,105		52,442			15.5
Total Liquids		1,129,004		1,119,419		9,585			0.9

Export revenues from our Liquids Production and Commercialization segment command a price premium, as compared to our domestic market sales, primarily as a result of regulation of domestic prices See “Item 8. Financial Information—A. Consolidated Statements and Other Financial Information—Exports.”

For the years ended December 31, 2022 and 2021, the total accrued exports withholding amounted to Ps.3,659 million and Ps.3,070 million, respectively.

In the domestic market, the Secretary of Energy continued issuing a series of measures with the aim of reducing the impact of the subsidies in public accounts in order to reduce the negative impact that the participation in the Households with Bottles Program and Propane for Networks Agreement have in the results of operations of natural gas liquids producers. These measures include an increase in the sales price from selling LPG bottles the above-mentioned agreements.

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The sales prices under the program for fiscal years 2022 and 2021 were as follows:

Resolution Nro.	Period	Ps. Per ton (at values determined by each resolution)
249	April 2021 to April 2022	Ps. 12,627
270	April 2022 to July 2022	Ps. 15,152
609	July 2022 to August 2022	Ps. 17,500
609	September 2022 to October 2022	Ps. 18,375
861	November 2022 to December 2022	Ps. 26,801

Over the first months of 2023, the Secretary of Energy approved further price increases. On August 25, 2021, the Secretary of Energy issued Resolution No. 809/2021, which establishes a Temporary Economic Assistance aimed at operators in the LPG industry (producers, fractionators, and distributors). The Transitory Economic Assistance provides for the recognition of 20% on the invoicing of the sale of LPG destined for the Home Program for the period August to December 2021, subsequently extended until March 31, 2022. On April 22, 2022, this assistance has been extended until December 31, 2022.

Under this agreement, we collect compensation from the Government, which is calculated taking into consideration the export parity price published monthly by the Federal Energy Bureau.

Regarding the Propane for Networks Agreement, during 2021, we signed the eighteenth extension by which the methodology for determining the price and volumes until December 31, 2021 was established. Regarding the agreement valid until December 31, 2022, it was signed on February 17, 2022.

See “Item 4. Our Information—B. Business Overview—Competition—Liquids Production and Commercialization—Regulation—International Market.” for additional information.

During 2022 the Liquids Production and Commercialization business segment recorded operating profit of Ps.38,901 million, compared to Ps.47,353 million in 2021. The main factors that affected the results of operations for this segment compared to 2021 were the following:

• Segment revenue decreased by Ps.4,345 million for the year 2022 compared to 2021. This negative effect was mainly due to the negative real exchange rate variation by Ps. 18,564 million and lower volumes of ethane and butane dispatched by Ps. 2,613 million. These effects were partially offset by higher ethane by Ps. 6,093 million and international benchmark prices by Ps. 5,015 million and higher volumes of natural gasoline and propane shipped by Ps. 4,784 million.

• Subsidies increased by Ps. 1,221 million in the year 2022 compared with 2021.

• In 2022 propane, butane and natural gasoline average export prices recorded increases of 5%, 8% and 16%, respectively, compared to 2021.

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• During 2022, the production of Liquids reached 1,129,004 tons (9,585 tons or 0.9% more than in 2021).

• It should be noted that there were no production restrictions during the winter period, as a result of a greater supply of local gas due to non-conventional gas developments;

• Notwithstanding the changes made to the Households with Bottles Program to supply butane to the domestic market described above, our obligations under this program continues to have an adverse impact on this segment, resulting, under some circumstances, in a negative operating margin on domestic sales of LPG;

• Costs of sales, administrative and selling expenses for the year ended December 31, 2022, increased by Ps. 3,518 million, to Ps. 65,352 million from Ps. 61,834 million, as compared to the year ended December 31, 2021. This increase was mainly due to higher: (i) cost of natural gas purchased as RTP of Ps. 3,131 million (principally as a consequence of the increase in the price of the natural gas), (ii) taxes of Ps. 657 million (especially tax on exports) and iii) salaries, wages and other compensations by Ps. 201 million. These effects were partially offset by technical operator assistance fees of Ps. 749 million; and

• Other operating expenses decreased by Ps. 589 million.

In 2022, export revenues from the Liquids Production and Commercialization segment were Ps.46,314 million and accounted for 28% (26% in 2021) of total net sales and 44% (41% in 2021) of total Liquids Production and Commercialization revenues.

In 2022, we exported propane and butane at spot prices, which allowed us to capture opportunities associated with different market niches, allowing us to considerably increase the individual fixed prices of each operation.

We sold our LPG exports at spot prices and to the date of this Annual Report, we are under negotiations for new agreements.

As in prior years, in the period ranging from May to September 2022, the sales of these products were conducted mainly in the domestic market, due to the restrictions in natural gas consumption for the production of Liquids and governmental requirements to supply the domestic market within the framework of the programs outlined by the Government for the supply of LPG.

Regarding the export of natural gasoline, after the termination of the term contract with Petrobras Global Trading B.V. traded until January 31, 2021, spot trades with Trafigura Pte Ltd were conducted until May. Starting in June, we traded with Trafigura Pte Ltd under a term agreement, with an extension until March 2023 inclusive.

In March 2023, we signed a new agreement with Trafigura to export natural gasoline. This agreement will expired in February 2024 and includes similar conditions as the previous one.

As mentioned above, overall international prices showed a rising trend, mainly in the first quarter of 2022, slightly contracting during the first half of the year and towards the year end. International prices are expected to increase in the short term, though below the averages of the first half of 2022. Additionally, as a result of the increase in sea freight costs, the prices at which our products are exported are foreseen to be subject to reduced margins, which could negatively impact the operating margins of the Liquids business segment.

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We keep expanding our positioning in the Brazilian market and in 2022 continued exports by sea to Brazilian LPG distributors, which started in 2021 in a direct modality, with no go-betweens. Besides, in September 2022 we conducted our first direct sea export to a Brazilian industrial user. Also, in December 2022, we conducted the largest LPG export to private Brazilian companies by sea.

Additionally, we export to Chile, Paraguay and Brazil by trucks. Volumes exported under this modality are lower than volumes exported by sea, which increased over the last several years, allowing us to capitalize a higher operative margin.

Regarding the price of natural gas, measured in U.S. dollars, acquired for RTP for processing at the Cerri Complex, it has suffered an increase of approximately 29% with respect to 2021 Said increase is related to the start up of the Gas.Ar Plan, implemented by the National Government, the aim of which is to generate the framework that facilitates the recovery of national gas production, establishing new market price references, added to a drop in the supply of certain productive basins and transportation restrictions from the Neuquén basin.

Although the Gas.Ar Plan could have a positive effect allowing to stop the fall in production levels that has been registered in the last periods, it is important to highlight the impact that it could have on the prices at which we would acquire the natural gas used in the Cerri Complex.

Other Services

This segment includes midstream services. Midstream services include natural gas treatment, separation and removal of impurities from the natural gas stream and compression services, which are generally rendered to the natural gas producers at the wellhead, as well as activities, related to construction, operation and maintenance of pipelines and compressor plants.

During 2022, the Other Services business segment recorded an operating profit of Ps.8,441 million, which represents a Ps.1,054 million increase compared to Ps.7,387 million in 2021. The main factors that affected the results of operations of this segment during 2022 are the following:

• Net revenues increased by Ps. 2,609 million primarily due to: (i) higher natural gas transportation and conditioning services in Vaca Muerta for Ps. 4,151 million, and (ii) compression of natural gas services by Ps. 621 million. These effects were partially offset by the decrease in the exchange rate on sales revenues denominated in U.S. dollars for Ps. 2,248 million and lower operation and maintenance services rendered by Ps. 132 million.

• Costs of sales, administrative and selling expenses increased by Ps. 1,601 million, mainly due to the increase in: (i) professional services fees by Ps.401 million, (ii) depreciations of Ps. 197 million, (iii) salaries, wages and other compensation by Ps. 177 million, and (iv) turnover tax by Ps. 186 million.

New Projects

Our strategy to focus on the client and innovation keep us centered on generating businesses and alternatives that allow us to achieve profitable investments and thus deliver value to our shareholders.

Thus, our Board of Directors approved several projects to expand the capacity of the Tratayén plant:

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• Installation of two modular gas conditioning plants through Joule Thomson technology, each with a treating capacity of 3.5 MM3/d of natural gas and a new gasoline stabilization tower. This project was started up in February 2023 and as of the date of issuance of this Annual Report is in operations. The estimated investment amounted to US$ 32 million.

• Installation of a 6.6 MM3/d capacity conditioning plant, which will require an estimated investment of US$ 132 million, with startup date foreseen in December 2023.

• Installation of a second 6.6 MM3/d capacity conditioning plant, which will require an estimated investment of US$ 138 million, with startup date foreseen by mid-2024.

These projects will expand Vaca Muerta System’s service rendering capacity, improving the profitability of the investment conducted by tgs and ensuring and guaranteeing the safety of the evacuation of producers’ gas volumes. Moreover, besides increasing conditioning capacity, these modules are convertible to processing activities with a low additional investment.

These projects also consolidate our commitment to the energetic development of Argentina and materialize our strategy to increase the profitability of our investments in the Vaca Muerta pipeline system. Hence, the building of the Nestor Kirchner Gas Pipeline recently announced by the National Government is of great relevance for this business segment, as it will allow us to enlarge our business portfolio in the region.

We are constantly in talks with different basins producers, seeking to seize business opportunities that may allow us to increase our service and clients’ portfolio.

Lastly, during 2022 we continued assessing new projects such as the construction of a gas liquefaction plant (LNG) in Bahía Blanca. This work poses an opportunity to exploit synergies with other natural gas production projects and would seize the domestic market demand drop during summer months.

Telecommunications

Telecommunication services are rendered by our subsidiary, Telcosur. During 2022, the Telecommunications business segment recorded an operating profit of Ps.86 million, compared to a profit of Ps.137 million in 2021. The main factors that affected the results of operations of this segment during 2021 are the following:

Net revenues increased by Ps.27 million in the year ended December 31, 2022, when compared to 2021.

Costs of sales, administrative and selling expenses increased by Ps.78 million in the year ended December 31, 2022, when compared to 2021.

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Year 2021 Compared to Year 2020

	Year ended December 31,
	2021			2020			Variation			Percentage of change
	(in millions of pesos)
Revenues		173,320			164,275			9,044			5.5
Net costs of sales		(92,843	)		(81,050	)		(11,794	)		14.6
Gross profit		80,476			83,226			(2,749	)		(3.3	)
Administrative and selling expenses		(14,336	)		(13,674	)		(662	)		4.8
Impairment of PPE		-			(9,155	)		9,155			(100.0	)
Other operating results		251			294			(43	)		(14.5	)
Operating profit		66,392			60,689			5,702			9.4
Net financial results		(850	)		(38,140	)		37,290			(97.8	)
Share of profit from associates		41			63			(21	)		(34.0	)
Income tax expense		(24,811	)		(12.950	)		(11,861	)		91.6
Total comprehensive income for the year		40,772			9,662			31,110			322.0

Total comprehensive income

For the year ended December 31, 2021, we reported a total net income and a total comprehensive income of Ps. 40,772 million, which represents a Ps.31,110 million increase compared to the total net income and total comprehensive income of Ps. 9,662 million reported in 2020.

The material factors affecting total comprehensive income were as follows:

• Net revenues to third-parties reached Ps. 173,320 million in 2021, which represents a Ps. 9,044 million increase compared to the 2020 fiscal year. This increase was mainly due to the growth in the Liquids Production and Commercialization and Other Services business segments revenues of Ps. 27,419 million and Ps. 2,996 million, respectively.

• Net cost of sales, including depreciation of fixed assets, reached Ps. 92,843 million in 2021, which represents a Ps. 11,794 million increase compared to the 2020 fiscal year. This increase was mainly due to: (i) the growth in the cost of natural gas processed in the Cerri Complex (mainly due an increase in price, measured in constant pesos) by Ps. 8,637 million, and (ii) the growth in expenses for repairs and maintenance of PPE and in their depreciation by Ps. 2,308 million.

• Administrative and selling expenses were Ps. 14,336 million in 2021, which represents a Ps. 662 million increase compared to the 2020 fiscal year. This increase was mainly due to higher tax on export of Ps. 1,831 million and depreciation of Ps. 604 million. These effects were partially offset, principally, by a decrease in turnover tax of Ps. 551 million, Ps. 409 million of the allowance for doubtful accounts and Ps. 300 million in salaries.

During 2021, subsidies increased by Ps. 3,224 million, this mainly driven by the increase in international prices and the lack of updating of the prices paid in the local market. For more information see Item 4. Our Information—B. Business Overview—Liquids Production and Commercialization.”

During 2020, we recorded an impairment of Ps. 9,155 million on our Natural Gas Transportation segment fixed assets as a consequence of the impairment test.

During 2020, we recorded a financial loss of Ps. 23,527 million generated by trading financial instruments to acquire foreign currency abroad.

Net cost of sales for the years ended on December 31, 2021 and 2020, represented 53.6% and 49.3%, respectively, of net revenues reported in the corresponding year.

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Administrative and selling expenses for the years ended on December 31, 2021 and 2020, represented 8.3%, in both years, of net revenues reported in the corresponding year.

See. “—Analysis of Operating Profit by Business Segment for the years ended December 31, 2021 and 2020.”

Share of profit from associates

For the year ended December 31, 2021, we recorded a profit from our investment in associates of Ps. 41 million, compared to the earnings of Ps. 63 million recorded in 2020.

Net Financial Results

In accordance with IAS 29 we presented the financial results in gross terms considering the effects of the change in the currency purchasing power in a single separate line. Gains and losses from monetary positions represent the effects of inflation on our monetary liabilities and assets, respectively.

Net financial results for the years ended December 31, 2021 and 2020, are as follows:

	Year ended December 31,
	2021			2020
	(in millions of pesos)
Financial income
Interest income		1,543			1,607
Foreign exchange gain		11,844			14,610
Subtotal		13,387			16,217
Financial expenses
Interest expense		(8,703	)		(9,874	)
Foreign exchange loss		(24,239	)		(43,622	)
Subtotal		(32,943	)		(53,496	)
Other financial results
Notes repurchase results		(807	)		1,174
Fair value (loss) / gain on financial instruments through profit and loss		(157	)		(21,363	)
Derivative financial instruments results		2.320			1,322
Other financial charges		(961	)		(1,053	)
Subtotal		395			(19,919	)
Gain on monetary position		18,311			19,059
Total		(850	)		(38,140	)

In accordance with the provisions of IAS 29, we opted to present the gain on the monetary position in a single line included in the financial results. This presentation implies that the nominal magnitudes of the financial results have been adjusted for inflation. The real magnitudes of financial results are different from the components of financial results presented above.

For fiscal year 2021, the net financial loss decreased by Ps. 37,290 million compared to the 2020 fiscal year. This variation is mainly explained by the gain recognized in Fiscal Year 2021 (loss in Fiscal Year 2020) for the operations carried out with financial assets at fair value, the lower loss for foreign exchange difference, net and interest generated by financial liabilities in real terms. These effects were partially offset by the loss generated in Fiscal Year 2021 from the repurchase of corporate bonds and the result of derivative financial instruments, when in 2020 we recorded a gain for such concepts.

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Income tax

Income tax for fiscal year 2021 was an expense of Ps. 24,811 million, compared to the expense of Ps. 12,950 million in fiscal year 2020.

The higher charge for income tax was mainly due to the increase in the applicable rate after the sanction of “Law No. 27,630: Modifies the income tax law” which, among other issues, introduces a modification in the rate of income tax in force for fiscal years or fiscal years beginning on or after January 1, 2021 inclusive. The amendment establishes a staggered system of rates in three segments according to the level of accumulated taxable net income: a first step of 25% for accumulated net income of up to $5 million pesos; the second step of 30% for accumulated net earnings of between $5 and $50 million pesos; and a last segment of 35% for accumulated net profits greater than $50 million pesos. This effect that was partially offset by the recognition of the specific tax loss recorded by the Company.

Analysis of Operating Profit by Business Segment for the Years Ended December 31, 2021 and 2020

The following table sets forth revenues and operating income for each of our business segments for the years ended December 31, 2021 and 2020:

	Year ended December 31,						Year ended December 31, 2020 compared to year ended December 31, 2019
	2021			2020			Variation			Percentage Change
Natural Gas Transportation(1)
Revenues from sales		49,484			71,584			(22,100	)		(30.9	)
Net cost of sales		(30,399	)		(29,219	)		(1,180	)		4.0
Gross profit		19,085			42,365			(23,280	)		(55.0	)
Administrative and selling expenses		(7,174	)		(7,943	)		769,0			(9.7	)
Impairment of PPE		-			(9,156	)		9,156			(100.0	)
Other operating expense		(397	)		(130	)		(267	)		205.7
Operating profit		11,514			25,136			(13,622	)		(54.2	)
Liquids Production and Commercialization
Revenues from sales		108,560			81,141			27,419			33.8
Net cost of sales		(56,281	)		(46,554	)		(9,726	)		20.9
Gross profit		52,279			34,587			17,692			51.2
Administrative and selling expenses		(5,553	)		(4,204	)		(1,349	)		32.1
Other operating income		627			412			215			52.6
Operating profit		47,353			30,794			16,558			53.8
Other services
Revenues from sales		16,138			12,833			3,305			25.8
Net cost of sales		(7,295	)		(6,938	)		(356	)		5.1
Gross profit		8,843			5,894			2,949			50.0
Administrative and selling expenses		(1,476	)		(1,394	)		(82	)		5.9
Other operating (expense) / income		20			7			13			172.2
Operating profit		7,387			4,508			2,879			63.9
Telecommunications
Revenues from sales		892			1,201			(309	)		(25.7	)
Net cost of sales		(623	)		(822	)		198			(24.1	)
Gross profit		269			380			(111	)		(29.1	)
Administrative and selling expenses		(132	)		(133	)		1			(0.7	)
Other operating expense		1			4			(4	)		(100.0	)
Operating profit		137			251			(113	)		(45.2	)

(1) Includes intersegment revenues of Ps. 1,754 million and Ps.2,483 million for the fiscal years 2021 and 2020, respectively.

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Regulated Natural Gas Transportation Segment

The Natural Gas Transportation business segment represented 27.5% and 42.1% of our total revenues during the years 2021 and 2020, respectively. Natural Gas Transportation revenues are derived mainly from firm contracts, under which pipeline capacity is reserved and paid for regardless of actual usage by the shipper. We also provide interruptible natural gas transportation services subject to availability of the pipeline capacity. In addition, we render operation and maintenance services for the Natural Gas Transportation facilities, which belong to certain gas trusts created by the Government to expand the capacity of the Argentine natural gas transportation pipeline system. This business segment is subject to ENARGAS regulation.

For additional information regarding the history of our discussions with various governmental authorities in relation to the adjustment of our gas transportation tariffs see “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Regulatory Framework.”

During 2021, the Natural Gas Transportation business segment recorded an operating profit of Ps.11,514 million, compared to a Ps.25,136 million profit recorded in 2020. The main factors that affected the results of operations of this segment compared to 2020 are the following:

• Revenues from the Natural Gas Transportation business segment decreased by Ps.22,100 million for the year 2021 compared to 2020;

• During 2021, we did not receive any tariff increase while annual inflation was 50.9%. The last tariff increase we received was in April 2019. During 2021, and within the framework of the Solidarity Law, our tariffs were frozen until the Government concludes the RTI or grants us a transitory tariff increase;

• Revenues related to natural gas firm transportation contracts for the year ended December 31, 2021, decreased by Ps.17,312 million for the year 2021 compared to 2020, as we have not received any tariff increase since April 2019, while the cumulative inflation rate for the Year 2021 was 50,9%. See “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Regulatory Framework—Regulation of Transportation Rates-Actual Rates” for additional information;

• Revenues related to interruptible natural gas transportation service decreased by Ps. 3,269 million for the year 2021 compared to 2020. The decrease mainly resulted from the lack of tariff increase discussed above, partially offset by higher volumes dispatched;

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• Revenues relating to the CAU decreased by Ps.789 million for the year 2021 compared to 2020 primarily as a result of the same tariff effect. The value of the CAU is much lower than the transportation tariff we are permitted to charge for our natural gas transportation services, because we were not required to make any investment in the construction and expansion of the assets to which the CAU relates. See “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Pipeline Operations—Pipeline Expansions” for additional information regarding the CAU;

• Costs of sales and administrative and selling expenses for the year ended December 31, 2021 increased by Ps. 411 million, from Ps. 37,572 million to Ps. 37,162 million, as compared to the year ended December 31, 2020. This increase was mainly attributable to higher PPE maintenance expenses of Ps. 1,880 million, as during 2021 we performed more repairs after the lockdowns and thought measures took in 2020 due to COVID, and Ps. 429 million of depreciation of PPE. These effects were partially offset, principally, by lower: (i) cost of third-party services of Ps. 1,134 million, (ii) salaries of Ps. 444 million and (iii) taxes of Ps. 403 million; and

• Other operating expenses increased by Ps. 267 million for the year 2021 compared to 2020, primarily as a result of higher provision for contingencies.

Liquids Production and Commercialization Segment

Unlike the Natural Gas Transportation segment, revenues of the Liquids Production and Commercialization segment are not subject to full regulation by ENARGAS and the Ministry of Energy. However, in recent years, the Government has enacted a number of laws and regulations that have limited our ability to receive the full international market prices for all of the liquids that the Cerri Complex produces. In addition, ENARGAS has the ability to redirect the volumes of natural gas in the system to cover certain uses and that may result in lower volumes of natural gas to be processed in the Cerri Complex. See “Item 4. Our Information—B. Business Overview—Competition—Liquids Production and Commercialization—Regulation” for more information.

The Liquids Production and Commercialization segment represented 62.6% and 49.4% of our total revenues during the years ended December 31, 2021 and 2020, respectively. Liquids Production and Commercialization activities are conducted at the Cerri Complex, which is located near Bahía Blanca and is connected to each of our main pipelines. At the Cerri Complex, we recover ethane, LPG and natural gasoline for our own account, on behalf of our customers and on a fee basis, collecting a commission for the extracted Liquids delivered to our customers.

For the fiscal years 2021 and 2020, all of our sales were made for our own account.

All ethane produced by our Liquids segment in the years ended December 31, 2021 and 2020 was sold locally to PBB.

Our ethane sales for the years 2021 and 2020 represented 24.6% and 33.7%, respectively, of our Liquids Production and Commercialization net revenues.

In 2021, we sold 55.1% of our production of LPG in the local market to LPG marketers, compared to 61.3% in 2020, with the remainder exported to LPG traders. In addition, all natural gasoline produced during 2021 and 2020 was exported. For more information about these contracts, see “Item 4. Our Information—B. Business Overview—Competition—Liquids Production and Commercialization.”

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The total annual sales for the Cerri Complex for 2021 and 2020 in tons were as follows:

	Years ended December 31,				Year ended December 31, 2021 compared to year ended December 31, 2020
	(volumes in tons)				(volumes in tons)
	2021		2020		Increase/ (Decrease)			Percentage Change
Local Market
Ethane		353,078		360,870		(7,792	)		(2.2	)
Propane		238,284		225,739		12,545			5.6
Butane		181,952		180,057		1,895			1.1
Subtotal		773,314		766,666		6,648			0.9
Exports
Propane		144,801		165,897		(21,096	)		12.7
Butane		85,627		90,612		(4,985	)		(5.5	)
Natural Gasoline		115,677		122,197		(6,520	)		(5.3	)
Subtotal		346,105		378,706		(32,601	)		(8.6	)
Total Liquids		1,119,419		1,145,372		(25,953	)		(2.3	)

Export revenues from our Liquids Production and Commercialization segment command a price premium, as compared to our domestic market sales, primarily as a result of regulation of domestic prices See “Item 8. Financial Information—A. Consolidated Statements and Other Financial Information—Exports.”

For the years ended December 31, 2021 and 2020, the total accrued exports withholding amounted to Ps.3,070 million and Ps.1 237 million, respectively.

In the domestic market, the Secretary of Energy continued issuing a series of measures with the aim of reducing the impact of the subsidies in public accounts in order to reduce the negative impact that the participation in the Households with Bottles Program and Propane for Networks Agreement have in the results of operations of natural gas liquids producers. These measures include an increase in the sales price from selling LPG bottles the above-mentioned agreements.

The sales prices under the program for fiscal 2021 and 2020 were as follows:

Resolution Nro.	Period	Ps. Per ton (at values determined by each resolution)
104	July 2019 to September 2020	Ps. 9,895
30	October 2020 to April 2021	Ps. 10,885
249	April 2021 to April 2022	Ps. 12,627

Under this agreement, we collect compensation from the Government, which is calculated taking into consideration the export parity price published monthly by the Federal Energy Bureau.

Regarding the Propane for Networks Agreement, during 2021, we signed the eighteenth extension by which the methodology for determining the price and volumes until December 31, 2021 was established. Regarding the agreement valid until December 31, 2022, it was signed on February 17, 2022.

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See “Item 4. Our Information—B. Business Overview—Competition—Liquids Production and Commercialization—Regulation—International Market.” for additional information.

During 2021 the Liquids Production and Commercialization business segment recorded operating profit of Ps.47,353 million, compared to Ps.30,794 million in 2020. The main factors that affected the results of operations for this segment compared to 2020 were the following:

• Segment revenue increased by Ps.27,419 million for the year 2021 compared to 2020. This increase was due to a Ps.33,358 million increases in prices. This effect was partially offset by the decrease in the volumes shipped by Ps.3,553 million and the exchange rate on U.S. dollar-denominated sales of Ps.5,497 million.

• In 2021 propane, butane and natural gasoline average export prices recorded increases of 104%, 89% and 85%, respectively, compared to 2020.

• During 2021, the production of Liquids reached 1,119,419 tons (25,953 tons or 2.3% less than in 2020).

• It should be noted that there were no production restrictions during the winter period, as a result of a greater supply of local gas due to non-conventional gas developments;

• Notwithstanding the changes made to the Households with Bottles Program to supply butane to the domestic market described above, our obligations under this program continues to have an adverse impact on this segment, resulting, under some circumstances, in a negative operating margin on domestic sales of LPG;

• Costs of sales, administrative and selling expenses for the year ended December 31, 2021, increased by Ps. 11,076 million, to Ps. 61,834 million from Ps. 50,758 million, as compared to the year ended December 31, 2020. This increase was mainly due to higher: (i) cost of natural gas purchased as RTP of Ps. 7,916 million (principally as a consequence of the increase in the price of the natural gas), (ii) taxes of Ps. 1,866 million (especially tax on exports), (iii) cost of third-party services of Ps. 789 million and (iv) maintenance expenses of PPE by Ps. 499 million. These effects were partially offset by lower doubtful accounts charges of Ps. 417 million; and

• Other operating expenses increased by Ps. 215 million.

In 2021, export revenues from the Liquids Production and Commercialization segment were Ps.44,709 million and accounted for 25.8% (17.1% in 2020) of total net sales and 41.2% (34.5% in 2020) of total Liquids Production and Commercialization revenues.

In 2021, we exported propane and butane at spot prices, which allowed us to capture opportunities associated with different market niches, allowing us to considerably increase the individual fixed prices of each operation.

We sold our LPG exports at spot prices and to the date of this Annual Report, we are under negotiations for new agreements.

As in prior years, in the period ranging from May to September 2021, the sales of these products were conducted mainly in the domestic market, due to the restrictions in natural gas consumption for the production of Liquids and governmental requirements to supply the domestic market within the framework of the programs outlined by the Government for the supply of LPG.

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Regarding the export of natural gasoline, after the termination of the term contract with Petrobras Global Trading B.V. traded until January 31, 2021, spot trades with Trafigura Pte Ltd were conducted until May. Starting in June, we traded with Trafigura Pte Ltd under a term agreement, with an extension until March 2022 inclusive.

In March 2022, we signed a new agreement with Trafigura to export natural gasoline. This agreement will expired in February 2023 and includes similar conditions as the previous one.

Additionally, we export to Chile, Paraguay and Brazil by trucks. Volumes exported under this modality are lower than volumes exported by sea, which increased over the last several years, allowing us to capitalize a higher operative margin.

Regarding the price of natural gas, measured in U.S. dollars, acquired for RTP for processing at the Cerri Complex, it has suffered an increase of approximately 41% with respect to 2020 The price increase experienced is related to the implementation of the Gas.Ar Plan, implemented by the National Government, which aimed to generate the framework that allows the recovery of national gas production, which set new market price references.

Although the Gas.Ar Plan could have a positive effect allowing to stop the fall in production levels that has been registered in the last periods, it is important to highlight the impact that it could have on the prices at which we would acquire the natural gas used in the Cerri Complex.

According to the two auctions carried out within the framework of the same, an increase in the PIST for thermal generation and for gas distributors was verified, which is highly likely to affect industrial users, which will finally impact on the costs of natural gas consumed in the Cerri Complex, thus affecting the operating margins of the business.

Other Services

This segment includes midstream services. Midstream services include natural gas treatment, separation and removal of impurities from the natural gas stream and compression services, which are generally rendered to the natural gas producers at the wellhead, as well as activities, related to construction, operation and maintenance of pipelines and compressor plants.

During 2021, the other services business segment recorded an operating profit of Ps. 7,387 million, which represents a Ps. 2,879 million increase compared to Ps. 4,508 million in 2020. The main factors that affected the results of operations of this segment during 2021 are the following:

• Net revenues increased by Ps. 2,879 million primarily due to: (i) higher sales revenues corresponding to natural gas transportation and conditioning services in Vaca Muerta for Ps. 3,305 million, and (ii) midstream services. These effects were partially offset by lower operation and maintenance services rendered by Ps. 304 million and the effect of the decrease in the exchange rate on sales revenues denominated in U.S. dollars for Ps. 828 million.

• Costs of sales, administrative and selling expenses increased by Ps. 439 million, mainly due to the increase in depreciations of Ps. 108 million, the increase in materials by Ps. 294 million, and the increase in turnover tax by Ps. 166 million This effect was partially offset by higher salaries, wages and other compensations by Ps. 131 million.

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Telecommunications

Telecommunication services are rendered by our subsidiary, Telcosur. During 2021, the Telecommunications business segment recorded an operating profit of Ps. 137 million, compared to a profit of Ps. 251 million in 2020. The main factors that affected the results of operations of this segment during 2021 are the following:

• Net revenues decreased by Ps. 309 million in the year ended December 31, 2021, when compared to 2020.

• Costs of sales, administrative and selling expenses increased by Ps. 199 million in the year ended December 31, 2021, when compared to 2020.

B. Liquidity and Capital Resources

We expect our main sources of liquidity in the near term to be cash flow from operations and, to a lesser extent due to the limited availability of financing for Argentine companies, cash flow from third parties obtained from financial institutions. As a consequence of the aforementioned, we closely monitor our liquidity levels in order to ensure compliance with our financial obligations and to achieve our objectives. Our principal uses of cash flows are expected to be capital expenditures, operating expenses, dividend payments to our shareholders, payments of financial debt and for general corporate purposes. We expect working capital, funds generated from operations and, to a lesser extent, financing from third parties to be sufficient. We assume that we will be able to access the domestic and international capital markets to refinance our 2018 Notes, if necessary.

To preserve cash surpluses, we invest in low-risk and highly liquid financial assets offered by high-quality financial institutions that are located in Argentina and the United States. Our policy is designed to diversify credit risk. Given that our total financial indebtedness is denominated in U.S. dollars, we prioritize the placement of funds in U.S. dollar-denominated investments.

We currently do not have any off-balance sheet arrangements or significant transactions with unconsolidated entities not reflected in our Financial Statements. All of our interests in and/or relationships with our subsidiaries are recorded in our Financial Statements.

In the short-term, the most significant factors generally affecting our cash flow from operating activities are: (i) fluctuations in international prices for LPG products, (ii) fluctuations in production levels and demand for our products and services, (iii) changes in regulations, such as taxes, taxes on exports, tariffs for our regulated business segment and price controls, (iv) fluctuations in the natural gas price used as RTP, (iv) fluctuations in exchange rates and (v) operating cost increases given inflation.

Our cash flows from operations have been affected in past years due to the lack of adjustment to our natural gas transportation tariffs to cover increases in our operating costs and capital expenditures. Along these lines, and as a guiding principle, financial solvency is our main objective.

During 2022, our cash generation has allowed us to cover all our financial needs, mainly the investments made for the maintenance of the transportation system and other operating assets of the remaining business segments, as well as those made for new projects.

In 2022, we have pursued the diversification of our investment’s portfolio. To that end, we acquired public and private bonds linked to the U.S. dollar and to CER (BCRA’s index: Stabilization Reference Coefficient) to mitigate the exchange rate risk on our liabilities in United States dollars and the impact of inflation on availabilities denominated in pesos. Besides, through several transactions, we acquired 2018 Bonds in a principal amount of US$ 7,262,000, for which we invested Ps. 2,453 million.

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The performance of the Natural Gas Transportation segment was marked by the lack of tariff updates, the last of which was received in March 2022 (the previous tariff increase had been received in April 2019), which in the framework of the Solidarity Law and its complementary rules provided for a tariff freeze and the renegotiation of the RTI.

During 2022, we continued participating in the Households with Bottles Program, which generates operating margins by virtue of the fact that the price determined by the SHR is significantly lower than the costs of processing natural gas. For further information, see “Item 4. Our Information—B. Business Overview—Liquids Production and Commercialization.”

The impact of the COVID in the financial markets has adversely affected the cost of borrowing, hedging activities and access to capital in general which could limit our ability to obtain hedges or financing in a timely manner, on acceptable terms or at all. In addition, the fragile economic environment in Argentina intensified by the slowdown in economic activity caused by the COVID and other internal factors may result in an increase in business failures among the clients we serve or may adversely affect the ability of our counterparties to perform their obligations under the transportations services or Liquids purchase agreements. As a result, our ability to generate sufficient cash from our operations in order to satisfy our indebtedness and capital expenditure needs may be adversely affected by the deterioration of Argentine economy due to the COVID.  The extent to which COVID may impact our operations, liquidity, financial condition, and results of operations will depend on future developments, including, but not limited to, the duration and spread of the pandemic, its severity, the actions to contain the disease or treat its impact, all of which are highly uncertain and cannot be predicted.

Considering our current lack of access to financial markets due to the current negative macroeconomic conditions, we believe that we will have to rely only on our operating cash inflow to meet our working capital, debt service and capital expenditure requirements for the foreseeable future. Actual results may differ materially from our expectations described above as a result of various factors affecting the Argentine economy.

In the Liquids Production and Marketing business segment, due to the high prices of commodities, we were able to maintain a positive cash flow.

As a result of a combination of external and local factors in the macroeconomic context, the exchange rate of the U.S. dollar increased by 72.5% during 2022, from Ps.102.72 to Ps.177.16. As of December 31, 2022, 89%, or US$404 million, of our fund placements were denominated in U.S. dollars, to mitigate such risk. During the period ended on December 31, 2022, sales revenues denominated in U.S. dollars amounted to 65%.

The foregoing allows us to conclude that we managed to limit the impact of the recent turbulence in the exchange rate on the future cancellation of indebtedness.

A further devaluation of the peso or further inflation with no compensating effect in our natural gas transportation tariffs or lower liquids prices could harm our cash-generating ability and materially adversely affect our liquidity, our ability to carry out mandatory capital investments and our ability to service our debt.

Our financial position is and will be significantly dependent on its operating performance, our indebtedness and capital expenditure programs.

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Our primary sources and uses of cash during the years ended December 31, 2022, 2021 and 2020 are shown in the table below:

	Years ended December 31,
	2022			2021			2020
	(in millions of pesos)
Cash and cash equivalents at the beginning of the year		8,627			13,682			39,089
Cash flows provided by operating activities		35,414			59,024			83,838
Cash flows used in investing activities		(40,216	)		(58,991	)		(88,466	)
Cash flows provided by / (used in) financing activities		3,626			(1,869	)		(14,921	)
Net (decrease) / increase in cash and cash equivalents		(1,175	)		(1,836	)		(19,548	)
Foreign exchange gains on cash and cash equivalents		293			630			2,236
Monetary results effect on Cash and cash equivalents		(4,755	)		(3,848	)		(8,095	)
Cash and cash equivalents at the end of the year		2,989			8,627			13,682

In our opinion, the working capital is sufficient for the company’s present requirement.

Cash Flows Provided by Operating Activities

The cash flow generated by operating activities for the year ended December 31, 2022, decreased by Ps. 23,610 million, mainly due to higher income tax payments by. 17,327 million, lower net income adjusted by non-cash items (including depreciation and financial results accrued) by Ps. 14,039 million. These effects were partially offset by higher collections of trade and other receivables by Ps. 4,782 million and lower interest paid by Ps. 1,579 million.

The cash flow generated by operating activities for the year ended December 31, 2021, decreased by Ps. 24,814 million, primarily resulting from higher income tax payments by Ps. 4,930 million, lower collections received from derivative financial instruments by Ps. 2,018 million and the decrease in the working capital.

Cash Flows Used in Investing Activities

The cash flow used in investment activities for the year ended December 31, 2022, decreased by Ps.18,775 million, mainly driven by lower acquisitions of financial assets not considered cash and cash equivalents under IFRS by Ps.25,642 million. This effect was offset by higher funds earmarked for the acquisition of capital goods within the framework of projects for other services undertaken by Ps.6,513 million.

The cash flow used in investment activities for the year ended December 31, 2021, decreased by Ps.29,475 million, mainly driven by lower acquisitions of financial assets not considered cash and cash equivalents by Ps.25,070 million and by lower funds related to capital expenditures allocated to the midstream business in Vaca Muerta.

Cash Flows Provided by / (Used in) Financing Activities

Cash flow generated by financing activities, amounted to Ps. 3,626 million compared to the cash flow used in financing activities for Ps. 1,869 million for 2021. This effect was due to the net taking of financial debt carried out during 2022 as opposed to the repurchase of notes of 2021.

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The cash flow used in financing activities for the year ended December 31, 2021, decreased by Ps. 13,052 million, primarily resulting from lower repurchase of notes and the cancellation of financial debt.

Description of Indebtedness

As of December 31, 2022, 100% of our total indebtedness was entirely denominated in U.S. dollars. The following table shows our total indebtedness as of 2022 and 2021:

	2022		2022		2021
	(in millions of U.S. dollars) (2)		(in millions of pesos)
Current loans:
2018 Notes Interest		5		937		1,075
Bank loans		8		1,441		-
Other financial liabilities		2		377		-
Leasing		7		1,164		1,225
Total current loans		22		3,920		2,300
Non-current loans:
2018 Notes		470		83,292		95,458
Leasing		17		3,098		4,663
Bank loans		24		4,304		-
Total non-current loans		512		90,694		100,121
Total loans(1)		534		94,614		102,421

(1) Issuance expenses net.

(2) Converted at the exchange rate of Ps.177.16 per US$1.00, which was the selling exchange rate as of December 31, 2021.

In order to improve the maturity profile of our financial debt, on April 19, 2018, we launched the Tender Offer (as defined below) to purchase for cash any and all of our negotiable instruments class 1 issued in February 2014 (the “2014 Notes”), which expired on April 26, 2018, and settled on February 11, 2014. On April 27, 2018, US$80,083,898.25 in aggregate principal amount of the 2014 Notes (or approximately 41.80% of the 2014 Notes then outstanding), were redeemed pursuant to the Tender Offer and the remaining 2014 Notes were redeemed on May 2, 2018, pursuant to the provisions of the indenture, dated February 11, 2014, among Delaware Trust Company (successor to Law Debenture Trust Company of New York), as trustee, co registrar, principal paying agent and transfer agent, and Banco Santander Rio S.A., as registrar (the “2014 Indenture”). The redemption of the 2014 Notes was financed with the proceeds from the offering of the 2018 Notes.

On January 3, 2014, the CNV authorized the public offering through Resolution No. 17,226. Our Board of Directors proposed that the 2017 Shareholders’ Meeting authorize an increase of up to US$700,000,000 (or its equivalent in other currencies) of the medium-term note program approved by the CNV on January 3, 2014, for the issuance of short- and medium-term bonds not convertible into shares. On October 31, 2018, we obtained approval from the CNV for the extension of the program to January 3, 2024. On 9 October 2019, we obtained approval from the CNV for the extension of the program to US$1.2 billion.

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On May 2, 2018, within the framework of the 2017 short- and medium-term negotiable obligations program approved by the CNV, we issued the 2018 Notes with the following characteristics:

Amount in U.S.$	500,000,000
Interest Rate	6,75% annual
Pricing	99,725%

	Date of Payment	Percentage on the Principal Amount to be Paid
Amortization	May 2, 2025	100%
Frequency of Interest Payment	Semiannual, payable on May 2 and November 2 of each year.
Guarantor	None.

The proceeds obtained from the 2018 Notes were used to: (i) repurchase the 2014 Notes for an amount equivalent to US$86,511,165; (ii) cancel and totally redeem the 2014 Notes for US$120,786,581; and (iii) make capital investments with the remaining balance.

As of December 31, 2022 the principal amount of outstanding 2018 Notes was U.S.$ 500 million. During 2022 and 2021, the Company repurchased its marketable debt for a nominal value of US$ 29.7 million and US$ 4.8 million for which it paid Ps. 2,453 million and Ps. 1,869 million, respectively. This transaction generated a result of (Ps. 1,030 million) and (Ps. 807 million), respectively, recognized in the financial results of the Statement of Income.

We are subject to several restrictive covenants under our 2018 Notes that limit our ability to obtain additional financing, including limitations on our ability to incur additional indebtedness to create liens on our property, assets or revenues. In addition to the required principal amortization payment obligations, we are also subject to other restrictive covenants that affect our use of cash on hand, such as limitations on our ability to pay dividends to our shareholders and limitations on our ability to sell our assets. See “Item 10. Additional Information—C. Material Contracts—Debt Obligations” for a detailed discussion of the terms of our financial debt, including the interest rates and material covenants applicable to such indebtedness.

During the third quarter of 2022, the Company incurred new financial indebtedness according to the following detail:

On March 31, 2022, the subsidiary Telcosur, took a loan for US$24 million. The main terms of such loan are:

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We regularly implement actions aimed at minimizing the impact of the exchange rate variation on our financial indebtedness, including entering into currency-forward agreements with major financial institutions for the purchase of U.S. dollars to cover exposure to the exchange rate risk derived from our financial indebtedness. In addition, we are able to invest in financial instruments, which reflect the variation of the exchange rate. During 2022 and 2021, we did not enter into any derivative instruments to hedge the foreign exchange risk.

Future Capital Requirements

As of December 31, 2022, our estimated material short-term and long-term contractual cash obligations consist of our borrowings, purchases of natural gas used in our Liquids Production and Commercialization business segment, and lease commitments and are detailed by maturity in Note 22 to our Financial Statements.

For the years of 2023 and 2024, our Board of Directors has approved a capital expenditure program in an amount of US$132 million and US$138 million, which will be mainly focused in our investments in Vaca Muerta area. For additional information see “Item 5.  Operating and Financial Review and Prospects—A. Operating Results—Discussion of Results of Operations for the Years Ended December 31, 2022 and 2021—Other Services.”

Operation of our assets imply that we must incur in capital expenditures to comply with the safety and maintenance of our natural gas pipeline system and other facilities of our business segments.

We currently expect to continue to rely on cash flow from operations and short-term and long-term borrowings and other additional financing activities to finance capital expenditures in the near term.

Our level of investments will depend on a variety of factors, many of which are beyond our control. Among them we can mention changes in current regulations, including the status of negotiations with ENARGAS in order to conclude the RTI process, the development of the Vaca Muerta area and the increase in natural gas supply, changes in tax legislation, and the political, economic and social situation prevailing in Argentina.

Currency and Exchange Rates

Due to the fact that our entire financial indebtedness is denominated in U.S. dollars, any significant devaluation of the peso would result in an increase in the cost of paying our debt, and therefore, may have a material adverse effect on our results of operations. Our results of operations and financial condition are also sensitive to changes in the peso-U.S. dollar exchange rate because most of our capital expenditures, and the cost of natural gas used in our Liquids business are denominated in U.S. dollars.

Therefore, our primary market risk exposure is associated with changes in the foreign currency exchange rates because our debt obligations are denominated in U.S. dollars and 35% of our consolidated revenues were peso-denominated for the fiscal year ended December 31, 2022. Contributing to this exposure are the measures taken by the Government since the repeal of the Argentine Convertibility Act and the pesification of our regulated tariffs described elsewhere in this Annual Report. This exposure is mitigated in part by our revenues from our Liquids Production and Commercialization business segment, 87% of which are denominated in U.S. dollars for the year ended December 31, 2022. Likewise, 83% of the operating costs of this business segment for that period were denominated in U.S. dollars. For more information, see “Presentation of Financial and Other Information—Currency.”

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We place our cash and current investments in high quality financial institutions in Argentina and the United States. Our policy is to limit exposure with any financial institution. Our temporary investments primarily consist of money market mutual funds and Government bonds.

Our strategy will remain focused on mitigating both the exchange rate risk arising from our liabilities in dollars and the effect of inflation on our liquidity. In a hyperinflationary accounting environment, maintaining monetary assets generates loss of purchasing power and maintaining monetary liabilities generates a gain in purchasing power; provided that such items are not subject to an adjustment mechanism that compensates to some extent for these effects. The monetary loss or gain is booked in the statement of comprehensive income. During the 2021 and 2020 fiscal years, we have maintained a net liability monetary position. As of December 31, 2022, we are maintaining a net asset monetary position.

C. Research and Development, Patents and Licenses, etc.

Not applicable.

D. Trend Information

See “—A. Operating Results” and “Item 8. Financial Information—A. Consolidated Statements and Other Financial Information—Legal and Regulatory Proceedings.”

E. Critical Accounting Estimates

Not applicable.

Item 6. Directors, Senior Management and Employees

A. Directors and Senior Management

General. Management of our business is vested in the Board of Directors. Our Bylaws provide for a board of directors consisting of a minimum of nine principal directors and nine alternate directors and a maximum of 11 principal directors and 11 alternate directors. In the absence of one or more principal directors, alternate directors will attend meetings of the Board of Directors. Principal directors and alternate directors are elected at an ordinary meeting of shareholders and serve one to three-year renewable terms, as resolved by the shareholders, subject to reelection. Effective and alternate directors shall remain in their positions until substituted by the shareholders. In December 2019, the board approved the rules of its internal operation.

Under our Bylaws and Argentine law, the Board of Directors is required to meet at least once every three months. A majority of the members of the Board of Directors constitutes a quorum, and resolutions must be adopted by a majority of the directors present. In the case of a tie, the Chairman or the person replacing him at a particular meeting is entitled to cast the deciding vote. The Board of Directors may hold meetings either by members in physical attendance thereat or by communication among themselves through other means of simultaneous transmission of sound, images and words.

Current Board of Directors members were designated at the 2023 Shareholders’ Meeting. All the member of our Board of Directors were appointed until the shareholders’ meeting that considers the financial statements as of December 31, 2023.

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The Shareholders’ Agreement (as defined in “Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders—Shareholders’ Agreement”) contains provisions governing the voting of our shares held by CIESA, the election of the members of our Board of Directors and certain other matters.

In February 2015, the Executive Branch enacted Decree No. 196/2015, which complements the provisions of Decree No. 1278/2012, mainly extending indemnity and legal assistance coverage to directors and statutory committee members appointed by the Government in companies in which it has stock participation.

Decree No. 894/2016, established that directors appointed by the FGS shall have the functions, duties and powers established by the General Companies Act, the Capital Markets Law and all the rules applicable to the company in which they act as directors, its bylaws and other internal regulations. On November 19, 2020, Law 27,574 was published in the Official Gazette, which regulates the role of the representatives of the FGS in those companies in which it has a stake, providing that the FGS will dictate the rules that are necessary in order to regulate their appointment, function, responsibility, performance and remuneration, which has been regulated by Decree No. 1041/2020 and ANSES Resolution No. 57/2021.

The General Companies Act governs the way directors are appointed. The members of the Board of Directors are appointed by the shareholders at the general annual shareholders’ meeting or by the Statutory Committee, as the case may be, when authorized by the Bylaws. It is not mandatory to be a shareholder of the company to be eligible to be appointed as a director. Section 263 of General Companies Act mandates that up to one-third of the members of the board can be appointed by the “cumulative vote system.” The vote of each shareholder who chooses to use the “cumulative vote system” shall be multiplied by the number of members to be appointed; the result may be partially or fully allocated to any of the candidates. All of the shareholders are entitled to choose the “cumulative vote system,” in other words, not only ANSES has the right to appoint members to the Board of Directors through that system.

Duties and Liabilities of Directors. Under Argentine law, directors have the obligation to perform their duties with the loyalty and diligence of a prudent business person. Directors are jointly and severally liable to us, shareholders and third parties for the improper performance of their duties, for violating the law, our Bylaws or regulations, if any, and for any damage caused by fraud, abuse of authority or gross negligence. Under Argentine law, specific duties may be assigned to a director by our Bylaws, regulations or by a resolution of a shareholders’ meeting. In such cases, a director’s liability will be determined with reference to the performance of such duties; provided that certain recording requirements are met. Moreover, under Argentine law, directors are prohibited from engaging in activities in competition with us without express shareholder authorization. Certain transactions between us and directors are subject to ratification procedures established by Argentine law.

A director who participates in the adoption of a resolution or who advises on or recognizes such resolution, will be exempted from liability if he leaves written evidence of his objection and notifies the Statutory Committee before his liability is reported to the board of directors, the Statutory Committee, a shareholders’ meeting, or competent authority or before judicial action is exercised. Shareholder approval of a director’s performance terminates any liability of a director vis-à-vis the Company; provided that shareholders representing at least 5% of our capital stock do not object and that such liability does not result from a violation of the law, our Bylaws or regulations.

Causes of action against directors may be initiated by us upon a majority vote of shareholders. If a cause of action has not been initiated within three months of a shareholders’ resolution approving its initiation, any shareholder may initiate the action on behalf of and for our account.

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At the general annual shareholders’ meeting held on March 6, 1996, our shareholders approved the acquisition of civil liability insurance coverage for directors, Syndics and officers. Such coverage is common practice among public companies who seek protection for such persons against shareholders’ and other parties’ claims.

As of the date of this Annual Report, five of the principal directors of our Board of Directors qualify as independent as defined in the NYSE in Section 303A of its Listed Company Manual (the “NYSE Standards”), Rule 10A-3 under the Exchange Act and the CNV Rules. Three of the principal directors of our Board of Directors (all of whom are independent in accordance with the NYSE Standards and two of whom are independent in accordance with the CNV Rules) are also members of our Audit Committee. The remaining members of the Board of Directors are not independent. Under the independence requirements, a director is not independent if any of the following apply:

• Is also a member of the management body of the controlling entity or another company belonging to the same economic group by a relationship existing at the time of its election or that ceased during the three years immediately preceding.

• Is linked to the issuer or its shareholders that hold directly or indirectly “significant shareholding” or with companies in which these also have direct or indirectly “significant shareholding,” or was linked to them by a contract of employment during the last three years.

• Provides, or belongs to a professional corporation or association, which renders professional services to or receives any form of remuneration or fees (other than the corresponding remuneration for its position in the administration body) from the issuer, or those shareholders that have any direct or indirect “significant shareholding” in us or from corporations in which shareholders also have any direct or indirect “significant shareholding.”

• Directly or indirectly, holds five percent or more of shares entitled to vote of our capital or in a company which holds “significant shareholding” in the latter.

• Directly or indirectly, sells or provides goods or services to the company or its shareholders, who hold direct or indirect “significant shareholding” for an amount substantially higher than the compensation received from the position as members of the administration body. This prohibition covers commercial relations that took place during the last three years prior to the appointment as director.

• Has been a director, manager, administrator or principal executive of non-governmental organizations that have received funds, for amounts exceeding Ps. 800,000 from the company, its controlling entity and other companies of the group of which tgs is a part.

• Receives some payment, including participation in stock option plans, from the company or the companies in its same group, other than the fees to be received under his position as director.

• Has served as director at the company, its controlling entity or another company belonging to the same economic group for more than ten years. The condition of independent director will be recovered after at least three years have elapsed since the cessation of his position as director.

• Is a husband or wife, legal partner, close relative up to third degree of consanguinity or second degree of relationship that, in the case of being a member of the administrative body, would not be independent as set forth in the CNV regulations.

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In all cases, “significant shareholding” refers to those shareholders holding at least five percent (5%) of our common stock, or less in cases when they are entitled to appoint one or more directors per class of share, or have agreements with other shareholders relating to the management and administration of any such companies, or its controlling entity.

The following table reflects the current members of our Board of Directors, their respective positions on the Board of Directors and the year they were appointed to such position.

Additional information regarding the occupation and employment background of each of our regular directors is set forth below:

Name	Date of Appointment	Term Expires	Position	Position in Other Company
Luis Alberto Fallo	4/19/2023	2024	Chairman	Director of Sagua Argentina S.A.
Horacio Jorge Tomás Turri	4/19/2023	2024	Vice Chairman	Executive director oil and gas at Pampa Energía
Pablo Viñals Blake	4/19/2023	2024	Director	Partner at Marval O’Farrell Mairal Law Firm
María Carolina Sigwald	4/19/2023	2024	Director	Legal Executive director at Pampa Energía
Luis Rodolfo Secco	4/19/2023	2024	Independent Director	Economist
Carlos Alberto Olivieri	4/19/2023	2024	Independent Director	Independent Consultant
Carlos Alberto Di Brico	4/19/2023	2024	Independent Director	Public Accountant
Lucas Gobbo	4/19/2023	2024	Independent Alternate Director	Director of Planning and Evaluation at ANSES
Ignacio Amigorena	4/19/2023	2024	Independent Director	Director General of Planning at ANSES
Jorge Romualdo Sampietro	4/19/2023	2024	Alternate Director	Senior Director at Petroquímica Cuyo
Gerardo Paz	4/19/2023	2024	Alternate Director	Pampa Energía’s legal affairs vice president
Francisco Antonio Macías	4/19/2023	2024	Alternate Director	Partner at Marval O’Farrell Mairal Law Firm
María Agustina Montes	4/19/2023	2024	Alternate Director	Legal affairs and compliance manager at Pampa Energía
Enrique Llerena	4/19/2023	2024	Independent Alternate Director	Partner at Llerena – Amadeo Law Firm
Santiago Alberto Fumo	4/19/2023	2024	Independent Alternate Director	Independent consultant
Martin Irineo Skubic	4/19/2023	2024	Independent Alternate Director	Manager of Alliances and New Business Development Latam South at Elli Lilly Interamerica
Luis Angelo Vergara Guarnizo	4/19/2023	2024	Independent Alternate Director	Analyst at FGS - ANSES
Cindy Signorini	4/19/2023	2024	Independent Alternate Director	FGS - ANSES

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Luis Alberto Fallo holds a degree in Accounting from the Universidad de La Plata and a Master’s degree in Business Administration from the Universidad del CEMA (Center of Macroeconomic Studies). He currently serves as Director of Simali S.A., Executive Director of Sagua Argentina S.A., President of Beau Lieu S.A., President of Finca de Los Andes S.A., President of Petroquímica Cuyo SAIC, Vice President of Aguas de Santiago S.A., President of PEPCA S.A. and Vice President of CIESA, President of First Class Flights S.A., President of TGSLatam, and Vice President of Hostería Las Balsas S.A. Since 1992 he has worked with Grupo Sielecki, the main and controlling shareholder of several companies to which he serves as Director. He was born on January 29, 1960.

Horacio Jorge Tomás Turri is currently Executive Director of exploration and production of Pampa Energía. From August 1997 to March 2000, Mr. Turri was Chief Executive Officer of Hidroeléctrica Piedra del Águila. From 1994 to 1997, he was Chief Executive Officer of Gener Argentina S.A. Prior to 1994, he was Development Assistant Manager at Central Puerto S.A. From 1990 to 1992, Mr. Turri worked as investment project’s analyst for the oil, gas, and electricity sectors at SACEIF Luis Dreyfus. He also worked at Arthur Andersen & Co. and Schlumberger Wireline in 1987-1990 and 1985-1987, respectively. He is CIESA’s Chairman, as well. Mr. Turri is an Industrial Engineer and received his degree at Instituto Tecnológico Buenos Aires. He was born on March 19, 1961.

Pablo Daniel Viñals Blake holds a law degree from the Universidad Católica Argentina and a master law degree from Harvard Law School.  Mr. Viñals Blake has been a foreign associate in the New York office of Milbank Tweed Hadley & McCloy LLP and since 1997 is a partner in the Buenos Aires office of Marval, O’Farrell & Mairal. Mr. Viñals Blake is currently the co-head of Marval’s Mergers & Acquisitions team and head of the Private Equity and Venture Capital and the Agribusiness groups. He has represented domestic and multinational companies, private equity, hedge funds and financial institutions in most of the largest M&A, Agribusiness and project financing transactions in Argentina in the last two decades and advised multilateral financial institutions such as the IFC, IDB and the United States Eximbank on their Argentine operations. He currently serves as a board member of BlackRock Argentina Asesorias S.A., PEPCA S.A. TGSLatam Energia and CIESA. He was born on October 3, 1962.

María Carolina Sigwald has been a member of the Board of Directors of Pampa Energía since 2018 and serves as Executive Director of Legal Affairs of Pampa Energía. Ms. Sigwald worked at the legal department of Central Puerto S.A., and then served as an associate at the New York office at Chadbourne & Parke and then worked at the Corporation Interamericana de Inversiones (IIC) based in Washington. In 1998, Ms. Sigwald returned to Argentina and founded the firm Díaz Bobillo, Sigwald & Vittone, in which she served as an external consultant for energy companies. Before joining as a director at Pampa Energía, between 2015 and 2017, Ms. Sigwald was the director of regulatory and legal affairs at Edenor. Ms. Sigwald is also a member of the boards of CIESA, TGSLatam Energía, CITELEC, CT Barragán, Pampa Cogeneración, Plásticos de Zárate, Transba S.A. and President of Greenwind. Ms. Sigwald holds a law degree with honors from University of Buenos Aires. She was born on November 15, 1967.

Luis Rodolfo Secco holds a Bachelor’s degree in Economics and a Master’s degree in Banking Disciplines from the Universidad Nacional de La Plata. In 1990 he obtained a scholarship as a full time researcher at the Universitá degli Studi di Siena. Between 1992 and 1994, he was a researcher and director of the School of Banking Disciplines of the Universidad Nacional de La Plata. Between 1994 and 1999, he worked as Chief Economist of M.A.M. Broda and Associates. At the beginning of 2000 he was summoned to work in the government of the then president Fernando De la Rua as economic adviser to the Presidency and General Director of Strategic Analysis of the Secretary of State Intelligence, a position he held until January 2002. In 2002, Mr. Secco founded his economic consulting firm, Economic Perspectives, and is currently director and editor of the Economic Perspectives newsletter. Between 2004 and 2012 he was external director of the Department of Economics of Deloitte Argentina. Since 1988 he has served as a professor at the Faculty of Economic Sciences of the Universidad Nacional de La Plata. He is also a guest columnist for the newspapers La Nación, Perfil and El Economista. He was born on December 14, 1963.

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Carlos Alberto Olivieri holds a Public Accountant degree from the Universidad Nacional de Rosario and a postgraduate degree in Corporate Financial Management from the University of Michigan and Stanford University. At present, Mr. Olivieri is professor of Finance at Universidad Torcuato Di Tella. Between 2008 and March 2010, Mr. Olivieri acted as a financial advisor at Raymond James and, between 2002 and 2007, he worked for YPF as Chief Financial Officer (“CFO”) for Argentina, Brazil and Bolivia. Previously he acted as CFO of YPF S.A., Quilmes Industrial S.A. and Eaton S.A. and President of YPF GAS S.A. and Maxus Corporation (USA). He also had executive responsibilities in other industries, such as Aerolíneas Argentinas and Arthur Andersen & Co. and taught at the Universidad de Buenos Aires and University of Michigan. Mr. Olivieri is also member of the board of directors of Metlife Seguros S.A. and acts as financial advisor. He was born on May 14, 1950.

Carlos Alberto Di Brico holds a degree in Administration and Public Accountancy from the Universidad de Buenos Aires. He is a member of the board of NTN SNR Argentina SA, FDV Intive Argentina SA, Aristocrat Argentina PTY Limited, Perform Media Argentina SRL and Perform Content South America SAS. He has held several management positions at Eveready Argentina S.A. between 1975 and 1995. From 1995 to 1998, he was CFO at Stafford Miller Argentina S.A. Between 2001 and 2013, he served as CFO and later as CEO at Emerson Argentina. Between 2010 and 2017, he was a member of the board of directors of Camuzzi Gas Pampeana S.A. He was born on August 1, 1952.

Lucas Gobbo holds a degree in Economics from the University of Buenos Aires (UBA) and specializes in Finance (UNQ). He is a professor and researcher at the Universidad Nacional de Avellaneda (UNDAV) and has experience in the private and public sector. He is currently Director of Planning and Evaluation at ANSES and is a member of the Board of Directors of La Anónima and Edenor. He was born on August 28, 1993.

Ignacio Amigorena holds a degree in Economics from the Universidad Nacional de La Plata. He is currently planning director in the ANSES. He is also member of the board of directors of Transener. He was born in March 10, 1985.

Jorge Romualdo Sampietro holds a degree in Chemical Engineering from the Universidad de Buenos Aires and an Executive Program at Darden Business School - University of Virginia. Between 1968 and 1973, he worked as Technical Sales Manager at Dow Química Argentina. From 1973 to 1975, he was Export Manager at Petroquímica Mosconi. Since 1976, he has worked as Commercial and General Manager at several companies. Since 1994, he has been General Manager of Petroquímica Cuyo and currently holds the position of Director of Petroquímica Cuyo S.A.I.C. and of Alternate Director of CIESA and PEPCA. He was born on May 12, 1944.

Gerardo Carlos Paz. Mr. Paz obtained a law degree from Universidad Nacional de Córdoba. He has worked at several places such as ENRE from 1994 to 2000, Camuzzi Gas Pampeana from 2001 to 2007 and Pampa Energía S.A. since 2007. Mr. Paz holds a Master’s degree in business law. Mr. Paz serves as Vice Chairman of PACOSA and Transelec. He is also director of HIDISA, HINISA, TJSM and TMB and alternate director of CPB, CIESA and Transba. Mr. Paz is also a member of the supervisory committee of CAMMESA. He was born on October 24, 1968

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Francisco Antonio Macías holds a Law degree from the Universidad Católica Argentina and a Post Graduate degree in International and EC Law from the School of Law of the University of Siena, Italy and a Post Graduate Degree in International Operations from the National Foreign Office Institute of Argentina. Since 2002, Mr. Macías is a partner in Marval, O’Farrell Mairal law firm and is currently the head of Marval’s Oil & Gas practice. Before joining Marval he worked for the firm of Bazán, Cambré & Orts and for BBVA Banco Francés. He was born on January 19, 1967.

María Agustina Montes since June 2011 has served as Pampa Energía’s legal affairs and compliance manager. Previously she acted as legal counsel in Clearly, Gottlieb Steen & Hamilton LLP and Brochou, Fernández Madero & Lombardi. She obtained a Law degree from de Universidad de Buenos Aires. She was born on September 28, 1981.

Enrique Llerena holds a Law degree from the Universidad Católica Argentina. He also holds a degree in Diplomatie et administration des Organization Internationales from the Universite et Paris XI. Since 1982, he has been a partner of the law firm Llerena Amadeo. He has served as the principal director and member of the audit committee of various companies. He is currently the Managing Director of Tradelog S.A. He is also a partner at Llerena & Arias Uriburu. He was born on April 9, 1955.

Santiago Alberto Fumo graduated as a Public Accountant at the Universidad del Litoral, and he also holds a Master’s degree in Law and Economy for the Universidad Torcuato Di Tella. He currently works as an independent consultant in startups and takeovers. Additionally, he acts as syndic at Molinos Río de la Plata S.A., National Oilwell Varco MSW S.A., Tuboscope Vetco de Argentina S.A. and Antares Naviera S.A. He was born on December 10, 1960.

Martín Irineo Skubic serves as manager for alliances and development at Elli Lilly Interamerica. In addition Mr. Skubic has served as senior officer at Jergens Argentina S.A., Stafford Miller Argentina S.A., Eveready Argentina S.A. and Pistrelli, Díaz y Asociados. Mr. Skubic holds a degree in public accounting from Universidad de Buenos Aires and holds a Master in Business Administration from Universidad del CEMA.

Luis Angelo Vergara Guarnizo is a candidate for economist at the National University of Avellaneda (UNDAV). He works as Financial Analyst for Monitoring and Corporate Management of the Financial and Diversified Sector of the FGS-ANSES.

Cyndi Signorini is a candidate for agricultural engineer from the Universidad de Buenos Aires. She works as budgetary financial accounting analyst of the FGS-ANSES.

Executive Committee. In order to achieve more streamlined management of the Company, the 2017 Shareholders’ Meeting approved the amendment of our Bylaws for the purpose of allowing, within the scope of the Board of Directors, the possibility of constituting an executive committee (the “Executive Committee”), under the terms established by article 269 of the General Companies Act.

The Board of Directors is the body in charge of appointing the members of the Executive Committee, which will be made up of four members: the directors who have been appointed as our President and Vice President, and any other two directors elected by simple majority, with a mandate to serve for one year.

The Executive Committee will function with a quorum of the majority of its members; the quorum must include our President and Vice President. It will adopt its decisions unanimously and will have the powers determined by the Board of Directors.

The current composition of the Executive Committee was decided by the Board of Directors at its meetings of April 19, 2023. Luis Alberto Fallo, Horacio Jorge Tomás Turri, Pablo Viñals Blake and María Carolina Sigwald are in office for a term of one fiscal year, until the meeting that considers the financial statements as of December 31, 2023.

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Executive Officers. The following is a list of our executive officers as of the date of this Annual Report, their respective positions with us and the year they were appointed to such position:

Name	Year of Appointment	Position
Oscar Jose Sardi	2019	CEO
Claudia Trichilo	2019	Operations Director
Carlos Hector Sidero	2013	Human Resources Director
Alejandro Mario Basso	2016	CFO and Services Director
Hernan Diego Flores Gomez	2017	Legal Affairs Director
Juan Ignacio de Urraza	2020	Business Director
Rubén De Muria	2018	Institutional and Regulatory Affairs Director

There is no expiration term defined for the executive officers.

Below is a description of the main activities currently carried out by each of our executive officers, together with the biographical information thereof:

Oscar Jose Sardi received a Mechanical Engineering degree from the Universidad Nacional de Rosario and holds a major in Natural Gas from the Universidad de Buenos Aires. He also participated in a General Administration Program at the Universidad Austral. He worked for GdE between 1983 and 1992 and since then, he has held different positions in our operations area. In April 2005, he was designated as our Service Vice President, and subsequently appointed as our Operations Director from October 2016 until April 2019, when he was appointed as our CEO. He also acts as President of Telcosur and of TGU. He was born on September 1, 1955.

Claudia Beatriz Trichilo received a Chemistry degree and a post-graduate degree in Engineering from the Universidad de Buenos Aires. From June 1988 to December 1992, she worked at the Industrial Engineering Department of Gas del Estado. In 1992, Ms. Trichilo joined tgs as Chief of Technical Planning and held such position until December 2002, when she was appointed Technical Developments Manager. From 2007 to 2010, Ms. Trichilo acted as Coordinator of Operations until August 2019, when she was appointed as our Operations Vice President. She also acts as Vice President of CTG. She was born on March 21, 1963.

Carlos Hector Sidero graduated from Universidad de Buenos Aires as a Certified Public Accountant in Argentina. He worked with Isaura S.A. from 1981 through 1994. From 1994, he managed different areas within the Human Resources department at Eg3 SA and Petrobras Argentina. He joined us in March 2013 as Vice President of Human Resources. He was born on February 16, 1956.

Alejandro Mario Basso received a Public Accounting degree from the Universidad de Buenos Aires. He worked for Compañía Naviera Pérez Companc from 1987 to 1992, and for Quitral-Co S.A. from 1992 to 1994. From 1994 to 1998, he acted as our Planning and Corporate Control Manager, and between September 1998 and March 2008, he was our Planning and Control Vice President. Between March 2008 and October 2016, he acted as our Management Control and Corporate Governance Vice President. In October 2016, he was designated as our CFO and Services Vice President. He also acts as President of CTG, Vice president of Telcosur S.A. and Gas Link S.A., Alternate Director of TGU and Liquidator at EGS. He was born on October 13, 1961.

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Hernán Diego Flores Gómez received a Law degree from the Universidad de Buenos Aires. He is a co-founder and professor of the Hydrocarbons and Energy Industry Law post-graduate course at Universidad Católica Argentina, and he is also a co-founder and professor of the Petroleum and Natural Gas Law post-graduate course at Universidad de Buenos Aires, and professor of the Energy Master’s degree at the Energy Regulatory Activity Studies Center (“CEARE”). Additionally, Dr. Flores Gómez has a Master’s degree in Business Law from the Escuela Superior de Economía y Administración de Empresas (ESEADE), a Master’s degree in Finance from the Universidad del CEMA and a Postgraduate degree in Damage Law from Universidad Católica Argentina. He began his career in the National Judicial Branch. Throughout his career, he held various relevant positions on legal matters, institutional and management relationship at companies such as Capsa / Capex S.A., Pluspetrol S.A. and ENAP Sipetrol Argentina S.A. He was born on June 10, 1966.

Juan Ignacio de Urraza holds a degree in Chemical Engineering from the Universidad Nacional de La Plata. He completed several postgraduate courses in Strategic Management, Business Management, Management Development, Management Development and Advanced Leadership. Between March 1991 and July 1992 he worked at the Instituto de Investigaciones Fisicoquímicas, Teóricas y Aplicadas as a researcher in the Corrosion Department. From September 1992 to January 1993 he worked as a fellow at Petroken Petroquímica Ensenada. From July 1993 to September 1994 he worked first as a Process Engineer and then as a Consultant at A&C Analistas Económicos y Consultores de Empresas.  Between November 1994 and February 2005 he held different positions in Metrogas. In March 2005 he joined us as Liquids Commercial Head, until September 2007, when he took over as Natural Gas Liquids Commercial Manager. In November 2020 he was appointed Business Director. He was born on September 27, 1969.

Rubén De Muria received a Public Accountant degree from the Universidad de Buenos Aires. He obtained a Master degree in Regulations of Gas and Electricity Industries from CEARE. He worked for Chase Manhattan Bank Argentina and Perez Companc S.A. between 1985 and December 1992. In December 1992, he joined us as member of the Regulatory Matters and Rates Department. In August 2006, he was promoted to Regulatory Matters and Rates Manager. In December 2015, he was appointed as Institutional and Regulatory Affairs Executive Manager, and, finally in January 2018, as Institutional and Regulatory Affairs Vice President. He was born on January 31, 1964.

For additional information regarding the provisions included in the Shareholders’ Agreement for the election of our CEO, see “Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders—Shareholders’ Agreement.”

Indemnification of Officers and Directors. Under the Shareholders’ Agreement, the shareholders of CIESA require us to: (i) limit the liability of each of our officers, syndics and directors for all consequences of their acts or omissions, excluding acts or omissions where there is evidence of fraud or gross negligence and (ii) enter into agreements obligating us to defend, indemnify and hold harmless each of our officers, syndics and directors from and against all liabilities, losses, and other expenses incurred by each such officer, syndic or director in connection with a pending, threatened or completed civil, criminal, administrative or other proceeding, or any investigation that could lead to such a proceeding, by reason of the fact that such officer, syndic or director is or was one of our officers, syndics or directors, including claims alleged to be due to the negligence of such person, but excluding acts or omissions that involve fraud or gross negligence towards us.

B. Compensation

The remuneration paid by us during the year 2022 to the members of our Board of Directors and executive officers amounted to Ps. 95 million and Ps. 321 million, respectively. We do not grant pension or retirement plans or other benefits to members of our Board of Directors or to our executive officers.

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Executive officers are subject to a goal-directed management system with a variable remuneration program. Consensual objectives are in line with our global objectives, as the variable remuneration program links a portion of its compensation to the performance thereof and our performance. Total compensation of executive officers consists of a fixed portion (normal and usual remuneration) and a variable portion. The variable portion depends on the level of achievement of the “Outcome” objectives, which consist of economic and financial targets, and “Performance Results,” including business objectives that do not have an associated economic result. We measure achievement of these objectives annually, based on performance during the fiscal period.

C. Board Practices

For information on the term of office of our directors and executive officers, see “—A. Directors and Senior Management” above. The information in that section is incorporated herein by reference.

None of the members of our Board of Directors are party to any service contract with us or any of our subsidiaries providing for benefits upon termination of employment.

Audit Committee

According to the Capital Markets Law, publicly listed companies must have an Audit Committee “that will function on a collegiate basis with three or more members of the Board of Directors, the majority of whom must be independent under CNV regulations.” The Audit Committee operates under its Charter of Procedure, which was approved in its meeting held in 2013 in accordance with the requirements of the Capital Markets Law. The charter Procedure require that the majority of the members that form the Audit Committee must be independent according to the CNV’s standards. Audit Committee members are designated by a simple majority of the Board of Directors, at the first meeting following designation of the members of the Board of Directors, and they hold office until their successors are designated. The Audit Committee adopts its own regulations and must prepare a working plan for each fiscal year.

The Board of Directors meeting held on April 19, 2023 appointed the current members of the Audit Committee, who as of the date of this Annual Report are Carlos Alberto Di Brico, Carlos Alberto Olivieri and Luis Rodolfo Secco and their respective alternates, Martin Irineo Skubic, Santiago Alberto Fumo and Enrique Llerena. All of Audit Committee members meet the independence criteria set forth under Rule 10 A-3 of the Exchange Act, SEC regulations and NYSE Standards, but according to CNV rules Mr. Carlos Olivieri does not qualify as independent since he has served as director for more of ten years.

The Audit Committee’s mandatory duties are to:

- supervise the internal control and accounting systems as well as the reliability of the latter and all the financial information and other significant issues that are to be submitted to the SEC, CNV and BYMA in compliance with the applicable disclosure policies;

- supervise the application of information policies regarding our risk management;

- ensure that the market is informed about those operations where there may be a conflict of interest with one or more members of the Board of Directors, controlling shareholders or other parties as defined by the applicable regulations;

- express its view on the reasonableness of fees and stock option plans for directors submitted by the Board of Directors;

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- express its view as to compliance with laws and regulations and the reasonableness of the conditions of an issuance of shares (or convertible securities), in the case of a capital increase, excluding or limiting preferential rights;

- oversee compliance with the Code of Ethics (see “Item 16B. Code of Ethics”); and other relevant rules;

- issue a well-founded opinion on whether the terms and conditions of relevant transactions with related parties are according to market practice, within five business days from the receipt of a petition issued by the Board of Directors, and at any other time at which a conflict of interest exists or might exist;

- prepare an annual working plan for the fiscal year and notify the Board of Directors and the Statutory Committee within 60 days from the beginning of the period;

- fulfill all the obligations stated in our Bylaws and applicable laws and regulations;

- express its view on the Board of Directors’ proposals on whether to appoint the external auditors to be hired and monitor the auditors’ independence; and

- establish procedures for: (i) the receipt, treatment, investigation and administration of the complaints received by us regarding accounting, internal accounting controls or auditing matters; and (ii) the confidential, anonymous submission by our employees of concerns regarding questionable accounting or auditing matters.

Also, regarding the internal and external auditors, the Audit Committee must:

- review their plans; and

- evaluate and give an opinion on their performance when issuing the annual Financial Statements.

In evaluating the external auditors’ performance, the Audit Committee must:

- analyze the different services rendered by the external auditors as well as their independence, according to Technical Resolution (“TR”) No. 34 of the FACPCE, and any other related regulations issued by professional councils;

- report separately the fees billed as follows: (i) fees for external audit and other related services meant to provide reliability to third parties (e.g., special reports about internal controls, shareholding prospectuses, certifications and special reports requested by regulators, etc.); and (ii) fees related to other special services different from those mentioned above; and

- review independence policies of the external auditors in order to verify their fulfillment.

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Additionally, the Audit Committee must perform the following mandatory duties contained in the regulatory framework:

- Give a prior assessment, that shall be used by the CNV to require us to designate an external auditor as requested by minority shareholders, as long as such shareholders represent at least 5% of our common stock and provide a justified request (in those cases in which the minority shareholders’ rights might be affected) and if CNV understands the credibility of the damage invoked by said shareholders in order to carry out one or more specific reviews. The charges of such reviews shall be borne by the petitioning shareholders (Act No. 26,381, article 108.f);

- provide a well-founded assessment about an acquiring tender (Act No. 26,381, article 98); and

- issue a report supporting a Board of Directors’ resolution to buy back our shares (Act No. 26,381, article 64).

Once a year, the Audit Committee is required to prepare a plan for the fiscal year to be presented to the Board of Directors and to the Statutory Committee. The directors, members of the Statutory Committee, managers and external auditors must, when requested by the Audit Committee, attend its meetings, provide the Audit Committee with information and otherwise assist the Audit Committee in the performance of its functions. In order to better perform its functions, the Audit Committee may seek the advice of legal counsel and other independent professionals at our expense, pursuant to a budget approved by the shareholders, and we must provide the Audit Committee with access to the information and documents it may deem necessary to perform its duties.

According to CNV Rules, at least once a year and upon the filing of the annual Financial Statements, the Audit Committee shall issue a report to the shareholders, addressing how such committee performed its duties and the results of its work.

The aggregate compensation paid by us for the fiscal year ended December 31, 2022 to the members of the Audit Committee was Ps. 34 million. We do not provide pension, retirement or similar benefits to any member of the Audit Committee.

Statutory Committee

The Statutory Committee is our monitoring body as stipulated in Section No. 284 of the General Companies Act. Our Bylaws provide for a Statutory Committee consisting of three syndics and three alternate members (“Alternate Syndics”). In accordance with our Bylaws, two syndics and the corresponding Alternate Syndics are elected by a majority vote of the holders of our Class “A” shares. The remaining syndic and corresponding alternate syndic are elected by the majority vote of the remaining holders of our common stock. Each member of the Statutory Committee is elected at the general annual shareholders’ meeting and serves for a one-year renewable term. Members of the Statutory Committee must be lawyers or accountants qualified under Argentine law and, for the accountants, TR No. 45. Our directors, officers and employees may not be members of the Statutory Committee, all members must be independent. Our Bylaws require the Statutory Committee to hold meetings at least once per month.

The primary responsibilities of the Statutory Committee consist of monitoring our management’s compliance with the General Companies Act, our Bylaws and the shareholders’ resolutions, and without prejudice to the role of external auditors, reporting to the shareholders at the general annual shareholders’ meeting regarding the reasonableness of our financial information. Furthermore, the members of the Statutory Committee are entitled to: (i) attend Board of Directors, Executive Committee and shareholders’ meetings, (ii) call special shareholders’ meetings when deemed necessary and general annual shareholders’ meetings when the Board of Directors fails to do so, and (iii) investigate written inquiries initiated by the shareholders. The Statutory Committee does not control our operations or evaluate management’s decisions, which are the exclusive responsibility of the Board of Directors.

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The aggregate compensation paid by us for the fiscal year ended December 31, 2022 to the members of the Statutory Committee was Ps. 18 million. We do not provide pension, retirement or similar benefits for syndics and alternate syndics.

The following table sets forth the current membership of our Statutory Committee, each of whom was appointed at the 2023 Shareholders’ Meeting, the year when each member was initially appointed and the year when their term expires:

Name	Member since	Term Expires	Position
José Daniel Abelovich	4/21/2020	2024	Syndic
Pablo Fabián Waisberg	8/21/2020	2024	Syndic
María Valeria Fortti	4/21/2020	2024	Syndic
Marcelo Héctor Fuxman	4/21/2020	2024	Alternate Syndic
Fernando Pedro Tetamanti	8/21/2020	2024	Alternate Syndic
Héctor Horacio Canaveri	4/19/2023	2024	Alternate Syndic

The present principal occupations and employment history of our syndics are set forth below:

José Daniel Abelovich obtained a degree in Accounting from the Universidad de Buenos Aires. He is a founding member and partner of Abelovich, Polano & Asociados S.R.L., a member firm of Nexia International. Formerly, he was Manager of Harteneck, López y Cía/Coopers & Lybrand and has served as a Senior Advisor in Argentina for the United Nations and the World Bank. He is a member, among others, of the supervisory committees of Cresud, IRSA, Hoteles Argentinos, Inversora Bolívar, Banco Hipotecario S.A. and CIESA He was born on July 20, 1956.

Pablo Fabián Waisberg is a Certified Public Accountant from the University of Buenos Aires. He is currently an accounting and tax advisor. He is also a trustee of Petrosiel S.A., Areic S.A., Grainco S.A., Petroquímica Cuyo S.A., Sagua Argentina S.A., Noragua S.A., CIESA and Aguas de Santiago S.A. He was born on February 3, 1965.

Valeria Fortti obtained a degree in Accounting and a bachelor in Administration form the Universidad de Buenos Aires. She also holds a Master in Business Administration from the same university. Since 1994, she has been a trustee in the Argentine National Auditing Commission. She is also a member of the supervisory committees of Emprendimientos Energéticos Binacionales S.A., Nucleoeléctrica Argentina S.A. and TELAM S.E. She was born on December 20, 1973.

Fernando Pedro Tetamanti obtained a degree is Accounting from the Universidad de Belgrano. He is partner of Tycompany advisors.

Marcelo Héctor Fuxman obtained a degree in Accounting from the Universidad de Buenos Aires. He is a partner of Abelovich, Polano & Asociados S.R.L., a member firm of Nexia International. He is also a member, among others, of the supervisory committees of Cresud, IRSA, Inversora Bolívar and Banco Hipotecario S.A. He was born on November 30, 1955.

Compensation Committee

We do not have a compensation committee. Compensation decisions are made by our senior management.

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Corporate Governance Practices; NYSE Requirements

See “Item 16G. Corporate Governance.”

D. Employees

The following table sets out the number of employees per department as of December 31, 2022, 2021 and 2020:

	Number of Employees as of December 31,
Department	2022		2021		2020
General		2		2		2
Administration, Finance and Services		118		118		113
Human Resources		27		27		24
Legal Affairs		11		11		11
Public and Regulatory Affairs		11		11		11
Safety and Environmental		30		31		30
Business		73		76		73
Internal Audit		4		4		4
Operations		814		822		791
Trainees program		5		6		-
Total		1,095		1,108		1,059

The following table sets out the number of employees according to geographical location as of December 31, 2022, 2021 and 2020:

	Number of Employees as of December 31,
Location	2022		2021		2020
City of Buenos Aires		290		289		281
Province of Buenos Aires		444		455		414
Province of Chubut		54		59		62
Province of La Pampa		14		13		14
Province of Neuquén		141		138		134
Province of Río Negro		65		59		61
Province of Santa Cruz		84		92		91
Province of Tierra del Fuego		3		3		2
Total		1,095		1,108		1,059

As of December 31, 2022, 2021 and 2020, the number of temporary employees working for us was 51, 47 and 39, respectively.

Under Argentine law, in the event of a dismissal of an employee without cause, the employer is required to pay the terminated employee severance, the amount of which is regulated by the Argentine Labor Law (Section 245). The severance consists of payment of one month’s wages for each year of employment. The Argentine Labor Law stipulates limits to the severance payment; these limits affect only employees who earn high wages. However, the Supreme Court has ruled this severance payment limitation unconstitutional when it results in a loss of more than 33% for a terminated employee as compared to the unlimited amount.

On December 13, 2019, the Executive Branch issued Decree No. 34/2019 which for a 180-days term doubles the amount of compensation mentioned above. The Government went a step further amid the COVID pandemic, extending this measure on several occasions, most recently by Decree no. 39/2021, effective until April 24, 2021.

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The Supreme Court held the Law of Occupational Hazard Prevention unconstitutional as applied to contractors whose employees are injured in the course of employment, extending liability to the company that contracted with the contractor for the services.

Some courts have held that a company that contracts with a contractor for services is jointly liable for a contractor’s obligations to provide its workers and third-party service providers with social security benefits, wages, insurance, etc., even if the service for which the company contracts is not part of the company’s usual business.

Recent years presented an inflationary scenario that required numerous meetings with union representatives. We maintain a positive relationship with each of the employee unions with representation before our company. The fruits of this work were the agreements reached with each such union, which have been submitted to the national labor authority for approval and inclusion in existing collective bargaining agreements. Those agreements effectively prevented trade union conflicts and work stoppages.

Our collective bargaining agreements with our unions were approved by the competent Argentine authority and maintain their ultra-activity as established by current legislation. Regarding the salary corresponding to 2022, we signed agreements for the period of April 1, 2022 to March 31, 2023. This is a consequence of the fact that tgs salary period comprises from the month of April of each year to the month of March of the following year. We are currently in negotiations with trade unions to conclude bargaining agreements for the period April 1, 2023 – March 31, 2024, but the status of this negotiation remains uncertain.

As of December 31, 2022, 79% of our workforce is under trade union representation, having the same employment benefits. The unions that represent such employees are Unión del Personal Superior del Gas, Federación Argentina del Gas Natural de la República Argentina (which groups the unions of the capital, Bahía Blanca and Patagonia Sur) and Sindicato de Trabajadores de la Industria del Gas Natural Derivados y Afines of Neuquén and Río Negro.

E. Share Ownership

As of December 31, 2022, the following members of our board of directors and our senior management had an ownership interest in our Class B shares of: Carlos Olivieri (0.001%) and Oscar Sardi (0.005%).

Class B shares held by directors and trustees do not have different voting rights than the other shareholders holding Class B Shares. The directors, trustees and senior executives of the Company do not have options regarding the Company’s shares. There are no agreements that grant participation to employees in the assets of the Company, including the issuance or granting of options, shares or any other negotiable value.

F. Disclosure of a registrant’s action to recover erroneously awarded compensation

Not applicable.

Item 7. Major Shareholders and Related Party Transactions

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A. Major Shareholders

The following table sets forth certain information with respect to each shareholder known to us to beneficially own five percent or more of our common stock as of March 31, 2023:

Name of Beneficial Owner	Number of Shares(1)	Percent of Total Common Shares	Class
CIESA	405,192,594	51.00%	A
FGS	190,685,633	24.00%	B
Holders through BYMA	69,441,554	8.74%	B
Treasury shares	41,734,225	5.25%	B
ADRs through Citi	87,441,287(1)	11.01%	B
Total	794,495,283	100.00%	--

(1) Equivalent to 17,488,257 ADRs.

Our controlling shareholder is CIESA, which holds 51% of our common stock and all of our Class A shares and local and foreign investors hold the remaining shares of our common stock, distributed among minority holders with 25% and FGS (managed by ANSES) with 24%. CIESA is under co-control of Pampa Energía, which holds 50% of CIESA’s common stock, and GIP and PCT, who in the aggregate hold a combined 50% indirect ownership interest in the outstanding capital stock of CIESA, as follows: GIP holds 27.1% and PCT holds 22.90%.

The current ownership of CIESA is the result of the acquisition of CIESA which encompassed the following steps:

• On July 27, 2016, Pampa Energía acquired from Petrobras Internacional Braspetro B.V. all the stock and voting rights of Petrobras Participaciones S.L., the holder of the 67.1933% of the capital stock and voting rights of Petrobras Argentina and, consequently, the indirect control of Petrobras Hispano Argentina.

• On the same day, (i) Pampa Energía and its subsidiary Pampa Participaciones S.A. sold all of the capital stock and voting rights of PEPCA to GIP by 51%, WST S.A. (“WST”) by 45.8% and PCT L.L.C. by 3.2% and (ii) Pampa Inversiones S.A. transferred its status as beneficiary of the Trust to GIP and PCT, in a proportion of 55% and 45%, respectively. This transaction was authorized by ENARGAS on August 9, 2016, through Resolution No. I / 3939.

• On January 17, 2017, CIESA was informed of the exercise of the swap option agreed among Pampa Energía, GIP, WST and PCT LLC. Pursuant to such option, (i) GIP and PCT transferred to PHA (formerly Petrobras Hispano Argentina) their position as beneficiary of a trust formed to that purpose (the “CIESA Trust”) owning of 40% of the stock and voting rights of CIESA; and (ii) Pampa Energía and PHA (formerly Petrobras Hispano Argentina) transferred to GIP and PCT shares representative of 40% of the capital and voting rights of CIESA, while Pampa Energía kept a direct participation in CIESA of 10% of its capital and voting rights.

• On March 24, 2020, CIESA was informed of the transfer of the 40% capital stock owned by the CIESA Trust to PHA.

• On July 13, 2020, PCT acquired WST participation in PEPCA, or 4.58% of CIESA, which resulted in GIP and PCT owning in the aggregate 50% in CIESA.

• On January 5, 2022, Pampa Energía merged with PHA. By virtue of this, PHA transferred to Pampa Energía all of the shares it held in CIESA, and as of that date, Pampa Energía had a 50% direct participation in CIESA.

Pursuant to the Pliego and the terms of the 2018 Notes, CIESA may not reduce its shareholding below 51% of our share capital.

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FGS owns 24% of our common stock. On October 5, 2015, the Argentine Congress passed Law No. 27,181, declaring the protection of the Government’s shareholdings, including those forming part of the portfolio of the FGS, to be in the public interest, and creating the Argentine Agency of Government Investments in Companies as an enforcement authority. This agency was later replaced by the Secretary of Economic Policy and Development Planning of the Ministry of Finance. This agency is in charge of implementing any policies and actions related to the exercise by the Government of any rights arising out of the shares it holds.

In June 2016, the Argentine Congress passed Law No. 27,260, repealing or modifying earlier laws relating to the FGS. Among other things, Law No. 27,260 established that ANSES’ shareholding in public companies may not be sold, in most cases, without the prior authorization of the Argentine Congress if this sale represents a reduction in the FGS’s aggregate shareholding in public companies to below 7%.

Decree No 894/2016, which regulates Law No. 27,260, created the Secretary of Economic Policy and Development Planning. This new agency is responsible for executing policies relating to the exercise of rights corresponding to shareholdings of companies where the Government holds a minority interest. Decree No. 897/2016 states that the directors appointed by ANSES shall have the functions, duties and powers established by General Companies Act.

According to applicable regulations, any transfer or other action that limits, alters, cancels or modifies the destination, ownership, possession or nature of the shares held by the FGS which results in a decrease of the FGS’s holdings in a manner inconsistent with applicable law, shall not be conducted without prior express authorization of the Argentine Congress, with the following exceptions:

• Public takeover bids addressed to all holders of such shares at a fair price authorized by the CNV, under the terms of Chapters II, III and IV of Title III of the Capital Markets Law.

• Exchange of shares for other shares of the same or another company in the context of a merger, split or corporate reorganization processes.

All outstanding shares are entitled to one vote each and there are no preferred shares or any privilege.

On February 16, 2017, the special shareholders’ meetings of Pampa Energía and Petrobras Argentina approved the prior merger commitment, under which Pampa Energía will be the surviving entity and Petrobras Argentina will be dissolved without liquidation. The merger is effective as of November 1, 2016. Subsequently, on April 26, 2018, the CNV notified the Board of Directors of the approval of the merger, which was recorded in the Argentine commercial public registry on May 2, 2018.

Shareholders’ Agreement

As a result of changes in the shareholding of our controlling company, CIESA, a shareholders’ agreement was signed on August 29, 2005 (the “Shareholders’ Agreement”). This agreement governs certain matters relating to shareholder participation in CIESA and in us. This agreement grants the shareholders different rights and obligations with respect to us and CIESA, mainly regarding the designation of the members of our Board of Directors and our Statutory Committee.

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The following table shows the current CIESA’s shareholding:

Shareholder	Number of shares	Class of shares	Ownership (%)
Pampa Energía S.A.	319,409,348	A	50%
PEPCA S.A.	63,881,870	B	10%
PCT L.L.C.	114,987,364	B	18%
Grupo Inversor Petroquímica S.L.	140,540,114	B	22%
Total	638,818,696

As reported in “Item 4. Our Information—A. Our History and Development—Controlling shareholders,” the control of CIESA / tgs is divided into two groups, on the one hand Pampa Energía, and, on the other hand, GIP and PCT. Thus, CIESA is under joint control between Pampa Group and GIP/PCT Group.

Transfers of Our Shares. Sales or transfer of our Class A shares must be approved by the affirmative vote of the shareholders representing at least sixty percent (60%) of the ordinary voting shares issued by CIESA.

Acts that require special approval of the Board of Directors. The Shareholders’ Agreement determines which decisions must be approved by an absolute majority of our Directors, including, among others: (i) the approval of the sale of assets outside the ordinary course of business; (ii) the approval of the annual budget and any modification thereof; (iii) approval to borrow or incur operating expenses in an amount that exceeds, in both cases, more than 10% of the amount approved in the annual budget; (iv) the approval to make investments that exceed US$0.5 million; (v) the approval to establish or modify wage and compensation policies; and (vi) the termination or extension of the SATFO.

Changes in the shareholders’ structure of CIESA

For more information to respect of the changes in the shareholding composition of CIESA see above. On its behalf, the mentioned share changes were duly authorized by ENARGAS and by the National Commission of Defense of Competition of Argentina.

On August 9, 2016, ENARGAS authorized the transaction through Resolution No. I-3939/2016. Later, the exchange option was authorized by ENARGAS on December 29, 2016. Similarly, on January 10, 2018, the National Commission of Defense of Competition of Argentina, and subsequently on February 8, 2018, the Secretary of Commerce, approved the mentioned share changes as described above.

On March 24, 2020, CIESA was informed of the transfer of the 40% holding owned by the CIESA Trust to PHA.

In addition, on March 26, 2020, Pampa Energía informed to CIESA of the beginning of the reorganization process by means of a merger through absorption process between Pampa Energía, as absorbing company, and Pampa Cogeneración S.A. and PHA, as absorbed companies.

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This reorganization process, effective since April 1, 2020, will result in Pampa Energía holding the 40% stake of CIESA currently owned by PHA.

On January 5, 2022, Pampa Energía merged with PHA. By virtue of this, PHA transferred to Pampa Energía all of the shares it held in CIESA, and as of that date, Pampa Energía had a 50% direct participation in CIESA.

Repurchase of Shares

On May 9, 2018, our Board of Directors approved a first program for the acquisition of our Shares in the open market. Since then, our Board of Directors has approved new share repurchase programs. For additional information of such programs, please see “Item 16E. Purchases of Registered Equity Securities of the Issuer by the Issuer and Affiliated Purchasers.” As of December 31, 2021, we had 41,734,225 treasury shares, representing 5.25% of the total share capital. The acquisition cost of the same in the market amounted to Ps. 10,924 million (together with the trading premium on treasury stock of Ps. v3,169 million) which, in accordance with the provisions of Title IV, Chapter III, article 3.11.c) and e) of the CNV’s Rules, restricts the amount of the realized and liquid gains mentioned above that we may distribute to our shareholders.

B. Related Party Transactions

Transactions with related parties are carried out in the ordinary course of business according to common practices and in accordance with applicable laws and regulations.

SATFO

Pampa Energía is our technical operator, according to the approval of ENARGAS in June 2004, and subject to the terms and conditions of the SATFO which provides that Pampa Energía is in charge of providing services related to the operation and maintenance of the natural gas transportation system and related facilities and equipment, to ensure that the performance of the system is in conformity with international standards and in compliance with certain environmental standards. Pursuant to this agreement, Pampa Energía, also provides financial advice to us. For these services, we pay a fixed annual amount or a monthly fee based on a percentage of our operating income, the higher of the before mentioned. At the Shareholders Meeting held on October 17, 2019, certain modifications to the amount and term of this agreement were approved. For additional information see “Item 4. Our Information—B. Business Overview—Natural Gas Transportation—Pipeline Operations—Technical Assistance Services Agreement.”

Commercial transactions

In the normal course of business, we carry out transactions with related parties of the following nature:

• agreements for the purchase of natural gas used as RTP;

• natural gas transportation services;

• liquids sales; and

• compression and treatment of natural gas services. On November 1, 2016, Pampa Energía assigned the operation of the Río Neuquén area and its related contracts to YPF. Until that date, our transactions under those contracts were reported as transactions with related parties of our Other Services business segment.

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• The board of directors approved the formation of the UT together with SACDE. The corporate purpose of the UT is to assembly of pipes for the construction of the project of “Expansion of the Natural Gas Transportation and Distribution System” in the province of Santa Fé, called through National Public Bid No. 452-0004-LPU17 by the former MINEM (the “Santa Fe Work”).

• On October 27, 2017, tgs - SACDE UT executed the corresponding work contract with the former MINEM. UT will continue to exist until its purpose has been fulfilled, that is, once the work involved in the Santa Fe Work and until the end of the warranty period, set at 18 months from the provisional reception.

In addition, we have entered into a UT operation with SACDE through which work related to the construction of the Regional II - Recreo / Rafaela / Sunchales Gas Pipeline will be carried out. Construction works are still in progress.

Leasing with Pampa Energía

On August 11, 2016, we entered into a financial lease with Pampa Energía. The term of the agreement is for 10 years and it determines that during nine years and 11 months we will pay Pampa Energía a monthly fee of US$623,457, before taxes. A purchase option is established on the leased property in our favor to be exercised within 30 days prior to the termination of the agreement.

The objective of this financial lease was to finance the acquisition of property, plant and equipment located in the Río Neuquén hydrocarbon area for a net book value of Ps. 3,716 million, which allowed us to expand our midstream services provided in that area.

The details of significant transactions with related parties as of December 31, 2022, are as follows:

Revenues							Costs								Financial results
Company	Natural Gas Transportation		Production and commercialization of Liquids		Other Services		Gas purchase and others		Compensa -tion for technical assistance		Revenues for administrat ive services		Commercialization expenses		Interests expenses		Interest income / fair value results
	(in thousands of pesos)
Controlling shareholder:
CIESA		-		-		-		-		-		162		-		-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		1,471,413		3,583,230		3,972,829		5,826,231		3,067,198		-		-		382,649		-
tgs´ associates which exercises significant influence on the controlling shareholder:
Link		-		-		46,750		-		-		-		-		-		-
Other related companies:
SACDE.		-		-		7,203		-		-		-		-		-		-
Comercializadora e inversora S.A.		298,568		-		-		-		-		-		-		-
Transener S.A.		-		-		417		-		-		-		-
CT Barragan		-		-		17,459		-		-		-		-		-		96,408
Fundación tgs		-		-		-		-		-		-		31,059		-		-
Total		1,769,981		3,583,230		4,044,658		5,826,231		3,067,198		162		31,059		382,649		96,408

As of December 31, 2022, we have a balance of Ps. 2,571 million corresponding to dollar linked notes issued by CT Barragán S.A. that accrue an annual rate of 4% over the exchange rate established in BCRA Communication “A” 3500 and that amortize the total principal on June 4, 2023.

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Additionally, during the year ended December 31, 2022, the Company received from SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A., construction engineering services for Ps. 3,319 million which are activated within the balance of advances to suppliers.

For additional information regarding revenues, costs, and outstanding balances relating to transactions with related parties as of and for the year ended December 31, 2022, see Note 21 to our Financial Statements included in this Annual Report on Form 20-F.

C. Interests of Experts and Counsel

Not applicable.

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Item 8. Financial Information

 
A. Consolidated Statements and Other Financial Information

Our Financial Statements, which are set forth in the index to Financial Statements in Item 18, are filed as part of this Annual Report.

Exports

For additional information regarding our exports, see “Item 4. Our Information—B. Business Overview—Liquids Production and Commercialization.”

Legal and Regulatory Proceedings

In addition to the matters discussed below, we are a party to certain lawsuits and administrative proceedings arising in the ordinary course of business. Although no assurances can be given, we believe we have meritorious defenses, which we will assert vigorously to challenge all claims, and that possible liabilities from these claims will not have a material adverse effect on our consolidated financial position or results of operations.

Tax Claims

Turnover tax calculated on the natural gas price consumed by us as fuel

We have interpretative differences with several provinces regarding the liquidation of the turnover tax calculated on the natural gas used by us as fuel to render our transportation services. Several lawsuits have been initiated against us, which were concluded in a manner adverse to us.

As of December 31, 2022 and 2021, we recorded a provision of Ps. 1,657 million and Ps. 2,211 million, respectively, in respect of this claim under the line item “Provisions,” which amounts were determined in accordance with the estimations of tax and interests, that would be payable as of such date.

If our position regarding the turnover tax claims mentioned above fails and the turnover tax has to be paid, we are entitled to recover this amount by a transportation tariff increase as set forth in the License. However, there can be no guarantee that such tariff increase would be granted, notwithstanding the terms of the License.

Action for annulment of ENARGAS Resolutions

On April 11, 2012, we filed a judicial action before the National Court of First Instance in the Federal Administrative Litigation Court No. 1 (the “Court”) in order to obtain the declaration of invalidity of Decree No. 2,067/08 and the Gas Charge Resolutions as well as the declaration of unconstitutionality of the Natural Gas Processing Charge. As of the date of this Annual Report, the case is pending judgment.

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On July 5, 2012, the Court issued in our favor a precautionary measure that suspended the charge on the terms set forth in the Gas Charge Resolutions. This decision was appealed in different opportunities by the Government and as a result the term of the precautionary measure was limited to six months. However, at the end of such term, we were entitled to obtain a new precautionary measure for a similar period.

The National Court of Appeals in Contentious Administrative rejected the extraordinary appeal filed by the Government against the judgment of that court that confirmed the rejection made by the Court at the request of ENARGAS to declare abstract the legal action initiated by us in accordance with the precedent “Alliance” issued by the Supreme Court in December 2014.

On March 26, 2019, we were served notice of the first instance judgment rendered in the proceedings, which upholds the legal action filed by us and declares the unconstitutionality of Executive Decree No. 2,067/08, MPFIPyS Resolution No. 1451/08 and the Gas Charge Resolutions, as well as of any other act aimed at enforcing the Executive Decree No. 2067/08, and therefore declare invalid said regulations. On March 29, 2019, the Secretary of Energy appealed the judgment, which was granted on April 3, 2019. On October 29, 2019, the judge resolved to extend the injunction (“medida cautelar”) (which prevents the Government from requiring us to pay the charges for the period between November 2011 and March 2016) until April 29, 2020 or until the award becomes final, whichever occurs first. The injunction has been extended until July 1, 2021.

Our management believes we have sufficient valid arguments to defend our position, and thus, we have not recorded any liability from the charge for natural gas consumptions from the date of obtaining the injunction until April 1, 2016, and of the effective date of Resolution 28.

On May 14, 2021, we were notified of the judgment handed down by Chamber I of the Chamber in Administrative Litigation that (i) has revoked the decision of the First Instance Judge and (ii) has imposed the costs in both instances in the order caused. tgs considers that it possesses reasonable arguments to defend his position on the substantive question raised and, for that reason, he appealed the ruling of the Chamber in Administrative Litigation.

On June 4, 2021, we filed an extraordinary federal appeal against the sentence of the Chamber, which was answered by ENARGAS and the Government and was granted by the Court of Appeals itself on July 14, 2021, on the understanding that “At stake is the interpretation and scope of regulations of an unquestionable federal nature, such as Decree 2067/08 and MINPLAN Resolution No. 1451/2008, ENARGAS Resolutions No. 1982/11 and 1991/11, as well as articles 53 and 54 of Law 26,784”.

By virtue of the precautionary measure issued, and its 12 extensions obtained, as well as the favorable ruling obtained in the first instance, the existence of favorable precedents issued by the Supreme Court with respect to other processors of natural gas and the granting of the extraordinary appeal that will result in the Supreme Court ruling on the case, the Management of tgs and its legal advisors consider that they have solid arguments to defend their position and that it is probable the obtention of a favorable resolution to their interests on the substantive issue. Therefore, no provision has been made for the eventual liability for the increase in the charge to finance the importation of natural gas applicable to natural gas consumptions related to the processing activity at the Cerri Complex for the period between the date of obtaining the precautionary measure and April 1, 2016, the effective date of Resolution No. 28/2016.

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This resolution has annulled the acts that determined the value of the charge established by Decree 2067, for which as from April 1, 2016, ENARGAS and the body in charge of the collection thereof have ceased to collect the increase established by the Resolutions.

Regarding the last extension of the precautionary measure, expired on July 1, 2021, tgs has not required a new extension, by virtue of the premature procedural stage in which the appeal against the Court judgment is found.

Given the complex procedural instance, the nature of charge 2067, the background presented in this and other legal cases initiated against charge 2067, as of the date of issuance of this Annual Report, it is not possible to make a definitive quantification of the amount that should be paid by tgs in case of not obtaining a favorable ruling from the Supreme Court, while an eventual demand for payment in the current circumstances may be challenged and questioned by us in the framework of the corresponding administrative and judicial instances, where the amount of the charge that tgs may eventually be required to pay may be debated.

Turnover tax withholding in the Province of Buenos Aires

The Company was notified by ARBA regarding the initiation of various determinative procedures in which tgs is claimed for a total of Ps. 4.9 million (without fine or interest) for the omission as agent of withholding and collection of the turnover tax corresponding to the period July 2009 - June 2011. Given this determination, the Company presented to ARBA various elements of evidence that allow reducing substantially the amount claimed. As of the date of issuance of these consolidated financial statements, the Tax Court has not resolved the issue.

In March 2017, tgs partially canceled the debt claimed by ARBA, paying Ps. 2.9 million (stated in its original value) through the adhesion to the payment plans offered by the Province of Buenos Aires through Law 14,890. Adherence to these payment plans allowed partial cancellation of compensatory interest and all fines and charges claimed by ARBA.

As of the date of the issuance of these Consolidated Financial Statements, only two files remain in relation to the alleged failure of tgs to act as withholding and collection agent during 2009 and 2010. The Company’s Management considers that it has sufficient arguments to assert its defense so as of December 31, 2022 and 2021 and no provisions have been recorded for this concept.

Other Litigation

Below is a description of certain other litigation in which we are involved. No assurances can be provided as to the outcome of these proceedings.

Environmental matters

We are subject to extensive environmental regulations in Argentina. Our management believes that our current operations are in material compliance with applicable environmental requirements, as currently interpreted and enforced. We have not incurred in material environmental liabilities as a result of our operations to date. As of December 31, 2022, the total amount of these provisions amounted to Ps. 58,5 million.

Others

In addition to the matters discussed above, we are a party to certain lawsuits and administrative proceedings which involve taxation, labor claims, social security, administrative and others arising in the ordinary course of business. Our management and our legal advisors estimate that the outcome of these differences will not have significant adverse effects on our financial position or results of operations. As of December 31, 2022 and 2021, the total amount of these provisions amounted to Ps. 77 million and Ps. 221 million, respectively.

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Dividend Distribution Policy

According to Argentina’s General Companies Act, dividends may be lawfully declared and paid only out of retained earnings reflected in the financial statements that have been approved by shareholders, if losses for prior fiscal years have been absorbed, if the applicable payment has been expressly approved by our shareholders and applicable legal reserves have been created, as described below.

To that effect, every year our Board of Directors must submit our financial statements for the immediately preceding fiscal year, together with reports thereon by our statutory committee (“Statutory Committee”), for the consideration and approval of the shareholders at the General Annual Shareholders’ Meeting which must approve our annual financial statements and determine the allocation of net income for such year, within four months of the close of the fiscal year, that is, for tgs before April 30 of each year. Pursuant to the General Companies Act and the CNV Rules, we are required to allocate a legal reserve (“Legal Reserve”) equal to at least 5% of each year’s net income (as long as there are no losses for prior fiscal years pending to be absorbed) until the aggregate amount of such Legal Reserve equals 20% of the sum of (i) “common stock nominal value” plus (ii) “inflation adjustment to common stock,” as shown in our consolidated statement of changes in equity. If there are any losses pending to be absorbed from prior fiscal years, such 5% should be calculated on any excess of the net income over such losses, if any. Dividends may not be paid if the Legal Reserve has been impaired, nor until it has been fully replenished. The Legal Reserve is not available for distribution as a dividend.

Pursuant to our Bylaws, after the allocation to the Legal Reserve has been made, an amount will be allocated to pay dividends on preferred stock, if any, and an amount equal to 0.25% of the net income for the year will be allocated to pay the statutory employee profit-sharing. The balance of the retained earnings for the year may be distributed as dividends on common stock or retained as a voluntary reserve, as determined at the General Annual Shareholders’ Meeting. For information on dividend taxation, see “Item 10. Additional Information—E. Taxation.”

In addition, under the General Companies Act, our shareholders may establish additional voluntary reserves from time to time and for different purposes. Once established, the terms and conditions of any voluntary reserve cannot be changed without the prior approval of the shareholders.

In our Board of Directors meeting held on December 18, 2019, the Board approved a written dividend policy. This policy provides that in making its evaluation, our Board of Directors should consider our financial results, our liquidity, our future financing needs and other information, including economic and financial projections for both our and the economy as a whole. Each year, our Board evaluates whether to submit a distribution proposal to the shareholders’ meeting.

Nevertheless, there are a number of restrictions that limit our ability to distribute dividends, including:

• Per the Tax Reform, for fiscal periods beginning on January 1, 2018, distribution of dividends made to human persons and foreign beneficiaries are subject to a tax withholding which we must withhold and enter to the tax authority as a single and definitive payment when the dividends are paid. This additional tax will be 7% or 13%, depending on whether the dividends distributed correspond to earnings of a fiscal period at the enacted income tax rate of 30% or 25%, respectively. For these purposes it is considered, without admitting proof to the contrary, that the dividends that are made available correspond, firstly, to the oldest accumulated earnings.

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• The acquisition of treasury shares and the additional paid-up capital for the distribution of treasury shares in accordance with CNV Rules, restricts the amount of the retained earnings that the Company may distribute. See “Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders—Repurchase of Shares.”

• According to the BCRA regulations, under certain conditions, we have to obtain its previous authorization before transferring dividend payments outside of Argentina. For additional information see “Item 10. Additional Information—D. Exchange Controls.”

Further, our ability to make dividend payments may be limited by covenants in our existing debt instruments or in debt instruments we enter into in the future, and by our subsidiaries’ ability to generate income and cash flows to pay dividends to us. In particular, under the indenture dated May 2, 2018 (the “2018 Notes Indenture”), entered into with Delaware Trust Company as trustee, co-registrar, paying agent and transfer agent, and Banco Santander Rio S.A., as registrar, Argentine paying agent, Argentine transfer agent and representative of the trustee in Argentina, relating to the issuance of our class 2, 6.750% senior notes due 2025 (the “2018 Notes”), we may pay dividends as long as immediately after giving effect to such dividend payment we are able to incur at least US$1.00 (other than “Permitted Indebtedness” as defined in the 2018 Notes Indenture) under the limitation of debt covenant of the 2018 Notes Indenture. To incur debt (other than Permitted Indebtedness), the 2018 Notes Indenture requires that (i) no default exists under the 2018 Notes Indenture at the time of such incurrence and (ii) (a) the Consolidated Coverage Ratio (as defined in the 2018 Notes Indenture, which is the ratio of our consolidated adjusted EBITDA to our consolidated interest expense) would be greater than or equal to 2.0:1.0; and (b) the Consolidated Debt Ratio (as defined in the 2018 Notes Indenture, which is the ratio of our consolidated total indebtedness to our consolidated adjusted EBITDA) would be less than or equal to 3.50:1.0. See “Item 10. Additional Information—C. Material Contracts—Debt Obligations.”

Moreover, per CNV Rules the amounts subject to distribution are restricted up to the acquisition cost of treasury shares and the additional paid-up capital accounts balance as discussed elsewhere herein.

In addition, according to the transitory agreement 2022, and during its term, tgs will not be able to distribute dividends.

For additional information regarding dividend payment restrictions see “Item 3. Key Information—D. Risk Factors—Risks Relating to Our Shares and ADSs—Shareholders outside Argentina may face additional investment risk from currency exchange rate fluctuations in connection with their holding of our shares or ADSs represented by ADRs. Exchange controls imposed by the Government may limit our ability to make payments to the Depositary in U.S. dollars, and thereby limit ADR holders’ ability to receive cash dividends in U.S. dollars.”

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A summary of the dividends declared and paid during the five most recent fiscal years is set forth below:

	Dividends declared and paid
Year ended December 31,	(in millions of Ps.)(1)		(in millions of U.S.$)(2)		(Ps.per share)(1)		(U.S.$ per share)(2)		(U.S.$ per ADS)(2)
2018(3)		9,067		114.6		11.41		0.142		0.708
2019(4)(5)		17,683		222.4		22.78		0.286		1.432
2020		-		-		-		-		-
2021		-		-		-		-		-
2022		-		-		-		-		-

⁽¹⁾ Stated in Ps.at Current Currency.

(2) Stated in U.S. dollars translated from pesos at the exchange rate in effect on the payment date.

(3) At the General and Special Annual Shareholders’ Meeting held on April 10, 2018, our shareholders resolved to create a future dividends payment reserve in an amount equal to Ps.7,882 million. At its meetings held on July 6, August 8 and September 6, 2018, our Board of Directors approved to release such reserve in full to our shareholders in the form of cash dividend payments up to an amount equal to the aggregate amount of such reserve.

(4) At the General Annual Shareholders’ Meeting held on April 11, 2019, our shareholders resolved to create a voluntary reserve for capital expenditures, stock buyback and/or dividends in an amount equal to Ps.12,462 million and a cash dividend payment of Ps.12,506 million. At its meetings held on April 11 and October 31, 2019, our Board of Directors approved the partial distribution of such reserve to our shareholders in an amount equal to Ps.783 million the form of a cash dividend.

(5) Includes the dividend in kind approved by the General and Special Shareholders’ Meeting held on October 17, 2019 and our Board of Directors’ meeting held on October 31, 2019 consisting in 29,444,795 shares (0.052 shares per share or 0.262 per ADS) at a price of Ps.139.20, calculated by reference to the closing price of our shares in BYMA as of November 12, 2019, the day immediately preceding the date of distribution of such shares to our shareholders.

The General Annual Shareholders’ Meeting held on April 19, 2023 approved to allocate Ps.1,967 million to the Legal Reserve and to allocate Ps. 185,004 million to the “Reserve for capital expenditures, acquisition of treasury shares and/or dividends” (the “2023 Reserve”) and to delegate to the Board of Directors the decision to use the 2023 Reserve to make investments, distribute dividends or repurchase stock. The amount of the 2023 Reserve will be restated in constant pesos at any given time pursuant to CNV Resolution No. 777/2018. To determine the maximum distributable amount out of the 2023 Reserve, the restated amount of the stock that has actually been repurchased and the additional paid-up capital must be determined in advance, since an amount equal to such stock already repurchased cannot be released to shareholders pursuant to the provisions of the CNV Rules.

 
B. Significant Changes

No undisclosed significant change has occurred since the date of our Financial Statements.

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Item 9. The Offer and Listing

A. Offer and Listing Details

Not Applicable.

B. Plan of Distribution

Not Applicable.

C. Markets

The Argentine Securities Market. In Argentina, the oldest and largest exchange is the Buenos Aires Stock Exchange (“BASE”), founded in 1854. The BASE was the exchange on which the majority of equity trades in Argentina were executed. BYMA is the result of an alliance between BASE and Mercado de Valores de Buenos Aires S.A. (“MERVAL”), dated 2013. From April 17, 2017 all the shares previously listed in the MERVAL were transferred to BYMA without any further consequence for listed companies.

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As of December 31, 2022, the market capitalization of shares of the domestic companies (excluding mutual funds) listed on the BASE was US$ 28,468 million.

Securities may also be listed and traded through over-the-counter market brokers who are linked to an electronic reporting system. The activities of such brokers are controlled and regulated by the Mercado Abierto Electrónico S.A. (the “MAE”), an electronic over-the-counter market reporting system that functions independently from the BYMA. Under an agreement between the BASE and the MAE, trading in equity and equity-related securities is conducted exclusively on the BASE (now BYMA) and trading in corporate debt securities is conducted on both the MERVAL/BASE (now BYMA) and the MAE. Trading in Government securities, which are not covered by the agreement, may be conducted on either or both of the BYMA and the MAE. The agreement does not extend to other Argentine exchanges.

Changes to the legal framework of securities trading have been introduced, permitting issuance and trading of new, non-bank financial products in the Argentine capital markets, including commercial paper, new types of corporate bonds, futures and options. The Government deregulated brokerage fees and eliminated transfer and stamp taxes on securities transactions in November 1991.

The Capital Markets Law, enacted in December 2012, sets out the rules to govern capital markets, its players, and the securities traded therein subject to the CNV regulation and monitoring. On May 9, 2018, the Argentine Congress approved the Act on Productive Financing No. 27,440, which introduces significant reforms to the Capital Markets Law, the Law on Common Investment Funds No. 24,083, the Argentine Law No. 23,576, as amended by Argentine Law No. 23,962 (the “Negotiable Obligations Law”), and other regulations, with the objective of promoting the development of the local capital market. Among other items, the new law seeks to broaden the base of investors and companies that can participate in the capital market, promoting productive financing, especially with respect to micro, small and medium enterprises, creating a regime that promotes and facilitates their access to financing. Likewise, this law provides for the modification of certain tax provisions, tax regulations, regulations related to derivative instruments and a program for the promotion of financial inclusion. The reforms also establish some limitations to the powers granted to the CNV by the Capital Markets Law.

The Capital Markets Law provides rules and provisions guided by the following goals and principles:

• Promoting the participation of small investors, union associations, industry groups and trade associations, professional associations and all public savings entities in the capital market, particularly encouraging mechanisms designed to promote domestic savings and channel such funds towards the development of production;

• Strengthening mechanisms for the protection of and prevention of abuses against small investors and for the protection of consumers’ rights;

• Promoting access of small- and medium-sized companies to the capital market;

• Fostering the creation of a federally integrated capital market through mechanisms designed to achieve an interconnection of computer systems from different trading markets, with the use of state-of-the-art technology; and

• Encouraging simpler trading procedures available to users to attain greater liquidity and competitiveness in order to provide the most favorable conditions for the implementation of transactions.

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The CNV is a self-administered agency of the Government with jurisdiction covering the territory of Argentina, governed by the provisions contained in the Capital Markets Law and the CNV Rules, among other related statutory regulations. The relationship of the CNV and the Argentine Executive Branch is maintained through the Ministry of Finance, which shall hear any appeals filed against decisions made by the CNV, notwithstanding any other legal actions and remedies contemplated in the Capital Markets Law.

The CNV supervises and regulates the authorized markets in which the securities and the collective investment products are traded, the corporations authorized in the public offer regime, and all the other players authorized to operate in the public offer regime, as the registered agents, the trading agents, the financial advisors, the underwriters and distributors, the brokers, the settlement and clearing agents, the managers of collective investment products, the custodians of collective investment products, the collective depositories, and the risk rating agencies, among others.

The BYMA. Pursuant to the Capital Markets Law, the CNV has authorized nine stock markets since September 2014. BYMA is a private entity whose stock capital is composed of publicly traded shares. On December 29, 2016, BYMA was authorized by CNV as a market, Registry No. 639. BYMA’s main functions comprise trading as well as performing as a Clearing House and Central Counterparty (CCP) in the settlement and monitoring of transactions carried out through its trading systems.

BYMA’s main functions under the Capital Markets Law are as follows:

• issue regulations that allow stock brokers and brokerage firms authorized by the CNV to perform their duties;

• authorize, suspend and cancel the listing and/or trading of negotiable securities pursuant to the provisions set forth in its bylaws;

• issue regulations that ensure veracity in the record of prices and trades;

• issue the regulations and policies deemed necessary to ensure transparency in the trades conducted by member stock brokers;

• fix the margins that member brokers are to comply with for each type of trade BYMA guarantees; and

• set up arbitration tribunals.

These powers may be exercised by BYMA or delegated, in whole or in part, to other qualified entities. Accordingly, BYMA has entered into an agreement with BASE to enforce items b) and f), due to the fact that BASE has been authorized to operate as a qualified entity, pursuant to Capital Markets Law.

New York Stock Exchange. The ADSs, each representing five Class B Shares, are listed on the NYSE under the trading symbol “TGS.” The ADSs began trading on the NYSE in November 1994, and have been issued by the Depositary.

According to data provided by the Depositary, as of March 31, 2023, there were 17,488,257 ADSs outstanding. Such ADSs represented approximately 11.01% of the total number of issued and outstanding Class B Shares as of such date.

Market Capitalization. Investors in the Argentine securities market are primarily individuals, companies and institutional investors consisting of a limited number of mutual funds.

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C. Selling Shareholders

Not applicable.

D. Dilution

Not applicable.

E. Expenses of the Issue

Not applicable.

Item 10. Additional Information

A. Share Capital

Not applicable.

B. Memorandum and Articles of Association

Information contained in Item 14 of tgs’s Registration Statement on Form F-1 (Registration No. 33-85178) is hereby incorporated by reference.

Bylaws amendments

The ordinary and special shareholders meeting held on April 30, 2014, approved certain amendments of our bylaws. The purpose of these amendments was to provide our administration with greater flexibility to manage as well as adapt the Bylaws to the requirements of the Capital Markets Law. Below you will find a description of the amendments to our Bylaws:

• Subject to the approval of the annual shareholders meeting, the number of members of the Board of Directors may vary between nine and eleven directors and an equal number of alternate directors.

• The Board of Directors meetings may be held not only with the members present, but also with the members communicating remotely. Under our Bylaws, all members will have the same power to vote on a proposal and will be considered to constitute a quorum.

• The Audit Committee duties, which are in line with those requirements stipulated in the Capital Markets Law, were incorporated to our Bylaws. For additional information regarding Audit Committee duties, see “Item 6. Directors, Senior Management and Employees—C. Board Practices—Audit Committee.”

The amended Bylaws approved by the 2014 Shareholders’ Meeting held on April 30, 2014, were filed with our Annual Report on Form 20-F for the fiscal year ended December 31, 2015, and are incorporated by reference in this Annual Report as Exhibit 1.2.

The 2017 Shareholders’ Meeting amended our Bylaws in order to: (i) expand our corporate purpose in order to incorporate the development of complementary, accessory, related and / or derived activities of natural gas transportation, such as the generation and sale of electricity and the provision of other services for the hydrocarbons sector in general, and (ii) allow the creation of an Executive Committee of the Board of Directors under the terms of Article 269 of the General Companies Act. The purpose of these amendments is to provide management with greater flexibility in decision-making. In relation to compliance with the regulatory requirements, this modification has not received comments from ENARGAS, as informed by a note from ENARGAS dated April 25, 2017, nor from the CNV, which has accepted this amendment through a note dated April 18, 2017.

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On July 14, 2017, through the issuance of Resolution No. 18,852, the CNV approved the amendment to our Bylaws, which was approved by the General Inspection of Justice on July, 25, 2017. Such amendment to our Bylaws was filed with the SEC pursuant to current report on Form 6-K, dated April 12, 2017 (Commission File No. 1-13.396), and are incorporated by reference in this Annual Report as Exhibit 1.2.

The 2021 Shareholders’ Meeting amended our Bylaws in order to let shareholders meetings may be duly convened remotely. The CNV approved the amendment to our By-laws, which was approved by the General Inspection of Justice on November 19,2021.

General Resolution No. 830/2020 of the CNV — Remote meetings

As a result of the COVID pandemic and the social distancing measures set forth in Decree No. 297/2020, on April 3, 2020, the CNV issued General Resolution No. 830 (“Resolution 830”), to the effect that:

During the period in which the curfews and other transit restrictions remain in effect as a result of the state of health emergency resulting from the COVID pandemic, shareholders and directors meetings may be duly convened remotely, even in the cases in which the Bylaws or other organizational documents do not expressly provide so if: (i) all shareholders or directors as applicable, are able to participate and cast a vote; (ii) the means of communication allow the simultaneous transmission of sound, images and sound during the entire meeting, and (iii) the applicable call notice shall clearly inform the access mechanism, procedures and other details for shareholders or directors, as applicable, to participate in the applicable meeting. In addition, issuers are required to keep a digital copy of record of the meeting for a period of five years, which shall be available to any shareholder who requests it. The issuer’s audit body shall be required to verify that at all times the meeting is conducted in accordance with applicable procedures set forth in the organization documents of the issuer and Argentine laws.

The 2021 Shareholders’ Meeting approved the amendment of Article 14 of our Bylaws to contemplate the possibility of holding remote meetings. As of the date of issuance of this Annual Report this amendment has been registered by the CNV.

C. Material Contracts

Debt Obligations

2018 Notes

On May 2, 2018, we issued the 2018 Notes in the aggregate principal amount of US$500 million, the proceeds of which were used to redeem all of our then outstanding 9.625% of the 2014 Notes pursuant to (i) a tender offer to purchase for cash (the “Tender Offer”) any and all of our 2014 Notes launched on April 19, 2018, which expired on April 26, 2018, and (ii) the optional redemption provisions of the 2014 Indenture. On April 27, 2018, US$80,083,898.25 in aggregate principal amount of the 2014 Notes (or approximately 41.80% of the 2014 Notes then outstanding), were redeemed pursuant to the Tender Offer and the remaining 2014 Notes were redeemed on May 2, 2018 pursuant to the provisions of the 2014 Indenture.

The 2018 Notes were issued pursuant to the program, which provides for the issuance of up to a maximum principal amount of US$1,200 million in notes, and was authorized by resolutions of an extraordinary shareholders’ meeting dated April 25, 2013 and April 13, 2017, and by resolutions of our Board of Directors adopted on July 23, 2013, December 23, 2013 and June 29, 2017. The program was also authorized by the CNV by Resolution No. 17,262 dated January 3, 2014 and Resolution No. 18,938 dated September 15, 2017.

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The scheduled maturity date of the 2018 Notes is May 2, 2025. The 2018 Notes accrue interest at an annual fixed rate of 6.750%, payable semiannually.

We are also permitted to redeem the 2018 Notes in whole, but not in part, at a price equal to 100% of the principal amount outstanding if, as a result of any change in, or amendment to, the laws or regulations of Argentina or any governmental authority thereof or therein having power to tax or as a result of any change in the application or official interpretation of such laws or regulations, we become obligated to pay additional amounts with respect to the 2018 Notes and cannot avoid such obligation by taking reasonable measures available to us.

In the event that the Republic of Argentina, directly or indirectly, through any one or more controlled entities, as a result of a condemnation, nationalization, confiscation, seizure, compulsory acquisition, expropriation or otherwise under power of eminent domain becomes the “beneficial owner” (as defined in Rules 13d-3 and 13d-5 under the Exchange Act) of at least 51% of our outstanding shares with voting power, holders of the 2018 Notes are entitled to require us to purchase all or a portion of the 2018 Notes at a price in cash equal to 101% of the principal amount of the 2018 Notes so purchased. The 2018 Notes are general, direct, unsecured and unsubordinated obligations and rank at all times pari passu in all respects, without any preference among themselves, with all of our other present and future unsecured and unsubordinated obligations, other than obligations preferred by statute or by operation of law.

Covenants

We are subject to several restrictive covenants under the terms of the 2018 Notes, which include, among others, the following:

• limitations on our ability to terminate our License or take any action that, in our reasonable opinion, would result in the termination of the License. We may not agree to amend or waive any terms of the License unless such amendment or waiver would not, in our reasonable opinion, adversely affect (i) our ability to meet our obligations under the 2018 Notes on a timely basis or (ii) any material rights or interest of the trustee or the holders under the indenture or the 2018 Notes;

• a requirement that we not enter into or consent to any amendment, restatement or modification of the SATFO or any successor agreement thereto, other than an amendment, restatement or modification that is not materially adverse to us and our subsidiaries, taken as a whole;

• a limitation on our and our subsidiaries’ ability to create liens on our property, assets or revenues, other than certain permitted liens;

• a limitation on our and our subsidiaries’ ability to incur additional indebtedness unless we meet certain financial ratios and no event of default exists, other than certain permitted indebtedness;

• a limitation on our and our subsidiaries’ ability to pay dividends and making certain other restricted payments and investments with respect to any fiscal year or fiscal semester unless: (i) no event of default or potential event of default shall have occurred and be continuing and (ii) immediately after giving effect to such restricted payment, we would be able to incur at least US$1.00 of additional indebtedness pursuant to the limitation on indebtedness covenant;

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• limitations on our and our subsidiaries’ ability to enter into sale-leaseback transactions;

• limitations on our and our subsidiaries’ ability to enter into a transaction with an affiliate, unless such transaction is on terms that are not materially less favorable to us or our subsidiary than we or such subsidiary would obtain in a comparable arm’s-length transaction with a non-affiliate;

• a limitation on our and our subsidiaries’ ability to sell our assets; and

• a limitation on our and our subsidiaries’ ability to enter into a merger, consolidation or similar transaction.

Events of Default

The 2018 Notes include the following events of default, among others:

• default in the payment of principal, interest or any other amount due under the terms of the 2018 Notes after a specified grace period with respect to payments other than principal;

• breach of obligations contained in the 2018 Notes after a specified cure period;

• cross-default and cross-acceleration with respect to other debt obligations with an aggregate principal amount equal to or exceeding US$50 million;

• the occurrence of certain bankruptcy events or enforcement proceedings;

• enforcement of monetary judgments exceeding US$50 million; and

• the occurrence of certain material adverse events with respect to our License, such as the revocation, suspension for a period of greater than 180 days or termination of the License.

Financial Lease with Pampa Energía

On August 11, 2016, we entered into a financial lease agreement with Pampa Energía. Starting on such date and for a term of nine years and 11 months (the “Leasing Payment Term”), Pampa Energía is leasing to us certain assets for a book value as of December 31, 2022 of Ps.3,716 million, which we utilize in our Other Services business segment. Monthly lease payments to Pampa Energía amount to US$0.6 million, before taxes.

Within 30 days of the expiration date of the Leasing Payment Term, we may exercise the option to purchase the assets leased to us under the agreement. The purchase option price will be equivalent to US$0.6 million before taxes.

For additional information, see Note 13 to our Financial Statements included under “Item 18. Financial Statements.”

D. Exchange Controls

The following is a description of the main BCRA regulations concerning inflows and outflows of funds in Argentina. For further information regarding the full scope of current foreign exchange restrictions and control regulations, investors should seek advice from their legal advisors and refer to the applicable rules mentioned in the Annual Report, which are available at the website of the Argentine Ministry of Economy: https://www.argentina.gob.ar/hacienda and https://www.minfinanzas.gob.ar/, or the website of the BCRA: www.bcra.gov.ar. None of the information contained on either website is deemed to be incorporated by reference into this Annual Report.

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On September 1, 2019, the Argentine government issued Decree No. 609/2019, pursuant to which foreign exchange controls were temporarily imposed until December 31, 2019. On January 3, 2020, the Argentine government issued Decree No. 91/2019, which permanently extended the foreign exchange controls that expired on December 31, 2019. A consolidated text of the currently applicable exchange control regulations can be found in Communication “A” 6,844/2019, as amended, issued by the Central Bank on December 6, 2019. On December 27, 2019 and December 30, 2019, the Central Bank issued Communications “A” 6,854/2019 and “A” 6,856/2019, respectively, pursuant to which the exchange control regulations found in Communication “A” 6,844/2019 remain effective after December 31, 2019. A brief summary of the exchange control regulations in force as of the date of this Annual Report is set forth below.

Exports of Goods

Exporters of goods must repatriate, and settle in pesos through the foreign exchange market, the proceeds from exports cleared through customs after September 2, 2019. For operations with related parties and exports of certain goods, the regulations provide that exporters have 15 days from the time the export cleared customs, to settle the proceeds from such exports (i.e., convert the proceeds from the exports from foreign currently into pesos) in the foreign exchange market. For all other transactions, exporters have 180 days from the date the export cleared customs, to settle the proceeds from such exports in the foreign exchange market.

Moreover, through Communication “A” 6844, the BCRA reinstated the export proceeds monitoring system, setting forth rules governing such monitoring process and exceptions thereof. Exporters will need to appoint a financial entity in charge of monitoring compliance with the aforementioned obligations.

The regulations authorize the application of export proceeds to the repayment of: (i) pre-export financings and export financings granted or guaranteed by local financial entities; (ii) foreign pre-export financings and export advances settled in the MULC, provided that the relevant transactions were entered into through public deeds or public registries; (iii) financings granted by local financial entities to foreign importers; and (iv) financial indebtedness under contracts executed prior to August 31, 2019 providing for cancellation thereof through the application abroad of export proceeds. The application of export proceeds to the repayment of other indebtedness shall be subject to BCRA approval.

By means of Communication “A” 7123 dated October 1, 2020, the BCRA decided to admit the use of collections of foreign currency resulting from exports of goods and services to (i) payment of capital and interest on financial indebtedness with foreign creditors whose average life, considering payments of capital and interest services, is not less than one year; and (ii) repatriation of foreign investors’ direct investments in companies that do not control local financial entities, to the extent that the repatriation occurs after the date of completion and implementation of the investment project and, at least, one year after the entry of the capital contribution in the exchange market.

By means of Communications “A” 7570 and 7571 dated August 5, 2022, the BCRA established that, until November 30, 2022, exporters of goods may credit the amount in pesos received as consideration for the export collection settlement in a “Special Account for Exporters”, provided that they are funds obtained from any of the following transactions:

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(i) export collections entered under concept code B01 or discount without recourse from a foreign entity of credits for exports of goods (concept code B03), in both cases corresponding to a destination that obtained the customs shipping complement until August 4, 2022 and provided that the exporter settles the funds obtained not less than 30 calendar days prior to the collection date originally agreed with the buyer or to the date of the credit, as the case may be;

(ii) advance collections on exports of goods (concept code B02) remitted by the buyer for a product to be shipped not less than 60 calendar days after the settlement date; or

(iii) prefinancing of exports of goods from abroad (concept code B03), the cancellation of which shall commence at least 60 calendar days after the settlement date.

For such purposes, financial entities shall open “Special Accounts for Exporters” in pesos, in which only the credits listed above shall be admitted. The balances recorded in these accounts shall be credited on a daily basis according to the evolution of the U.S. dollar - Communication “A” 3500 - on the previous business day.

Sale of Non-Financial Assets

Proceeds in foreign currency from the sale of non-financial assets must be repatriated and settled in pesos in the foreign exchange market within five business days from the date of collection in Argentina or abroad, or the date of deposit of such amounts in foreign bank accounts.

Exports of Services

Exporters of services must repatriate, and settle in pesos through the foreign exchange market, the proceeds from their exports within five business days from the date of collection in Argentina or abroad, or the date of deposit of such amounts in foreign bank accounts.

Foreign Assets

Prior authorization from the Central Bank is required for the acquisition of foreign assets (e.g., purchase of foreign currency, among others) and for derivative transactions by Argentine companies, Argentine local governments, Argentine mutual funds, trusts and other Argentine entities. Individuals must request authorization when the value of such assets exceed US$200 (in the case of withdrawals from Argentine bank accounts) or US$100 (in the case of cash purchases) in any calendar month.

External Financial Indebtedness

Borrowers must repatriate and settle in the foreign exchange market the proceeds from financial indebtedness incurred after September 1, 2019, as a condition to be granted access to the foreign exchange market to make debt service payments thereunder. Subject to compliance with requirements set forth in the regulations, access to the foreign exchange market will be granted for the repayment of principal or interest up to three business days in advance of the due date.

Communication “A” 7,030, and its amendments, establishes the prior agreement of the Central Bank, until June 30, 2021, for the cancellation of capital services of financial debts with abroad, provided that the creditor is a related counterparty.

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Additionally, Communication “A” 7,106 established the requirement, for those who register scheduled capital maturities between October 15, 2020 and March 31, 2021 with creditors that are not related counterparties, to submit to the Central Bank a detail of a refinancing plan complying with certain criteria established in the said Communication. Specifically, the Central Bank will grant access to companies for an amount less than 40% of maturities and companies must refinance the rest for a term of at least two years. This, provided that the amount for which the exchange market would be accessed for the cancellation of principal exceeds the equivalent of US$1,000,000 per calendar month, with some exceptions, expressly provided for by the regulation.

Finally, the Communication established that for new debt securities with a public register in the country or abroad, issued as from October 9, 2020 in the framework of the refinancing processes provided for in point 7 of Communication “A” 7106, the requirement of foreign currency settlement for the purposes of access to the foreign exchange market for the cancellation of its capital and interest services will be deemed to be fulfilled. In this way, the BCRA would be ensuring that new securities issued under these exchange processes would have access to the foreign exchange market, even if there was no foreign exchange settlement from the issue.

On the other hand, Communication “A” 7123 provided that BCRA’s prior consent to access the exchange market will not be required in the following cases:

• Repatriation of foreign direct investments in companies that do not control local financial entities, insofar as the capital contribution has been entered and settled in the foreign exchange market as of October 2, 2020 and the repatriation takes place at least two years after entry.

• Payment at maturity of the principal of foreign financial indebtedness of the non-financial private sector when the creditor is a counterpart linked to the debtor, insofar as the funds have been entered and settled in the foreign exchange market as of October 2, 2020 and the indebtedness has an average life of no less than two years.

On January 6, 2021, the BCRA issued Communication “A” 7196, which provided for certain relaxations to the settlement of foreign currency originated in the process of taking or refinancing debt.

On January 7, 2021, the BCRA published Communications “A” 7200 and “A” 7201, according to which it resolved, on the one hand, to establish that those individuals and legal entities that are considered obliged subjects must complete the “Registry of foreign exchange information of exporters and importers of goods” before April 30, 2021 and, on the other hand, it established new measures to access the foreign exchange market for the import of goods defined as luxury and final goods.

On February 4, 2021, the BCRA issued Communication “A” 7218, which established a new option to access the foreign exchange market to pay principal and interest services of debt securities issues with registration abroad arranged as from February 5, 2021 and that have been partially subscribed in foreign currency in the country. In order to be eligible for this possibility, the following conditions must be met: (i) the debtor proves to have registered exports prior to the issuance of the debt securities or that the funds from the placement were destined to face commitments abroad; (ii) the average life of the securities must be no less than five years; (iii) the first amortization is agreed to occur no earlier than three years from the issue date; (iv) the local tranche of the issue does not exceed 25% of the total issued; and (v) at the date of access all the funds integrated under the issue have been liquidated.

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Communication “A” 7,030, and its amendments, establishes that prior authorization from the Central Bank shall be granted for the cancellation of capital services of financial debts abroad, provided that the creditor is a related counterparty, with limited exceptions.

Pursuant to this, the Central Bank may grant companies access to the MULC for up to 40% of any such debt, with the companies being required to refinance the outstanding 60% following certain guidelines established by the Central Bank.

Indebtedness Between Residents

Prior authorization from the Central Bank is required for the payment of foreign currency-denominated obligations between Argentine residents after September 1, 2019. However, no prior authorization is required for the payment of foreign currency-denominated obligations to Argentine financial entities, including, among others, payments made in respect of credit cards.

Access to the foreign exchange market by security trusts for principal and interest payments

Communication “A” 6844, local trusts created to guarantee principal and interest payments by resident debtors may access the MULC in order to make such payments at their scheduled maturity, to the extent that, pursuant to the current applicable regulations, the debtor would have had access to the MULC to make such payments directly. Also, subject to certain conditions, a fiduciary may access the MULC to guarantee certain capital payments and interest on financial debt abroad and anticipate access to it.

Profits and Dividends

Prior authorization from the Central Bank is required for the transfer of profits and/or dividends outside of Argentina, unless certain requirements expressly provided for by current regulation are met.

Non-Residents

Non-residents must obtain prior authorization from the Central Bank to access the foreign exchange market to purchase foreign currency, with limited exceptions.

Reporting Regime

In all cases, access to the foreign exchange market for the payment of financial or commercial debts will be granted to the extent that such debts were disclosed in accordance with the Central Bank’s reporting regime.

Outgoings

Imports of Goods and Services

Except for certain exceptions current regulations provide for, importers of goods and/or services must obtain prior authorization from the Central Bank for the settlement of foreign currency-denominated debts in connection with the import of goods and services.

Outflow of funds

Through Communication “A” 7,001, as amended by Communication “A” 7,030, the Central Bank established certain restrictions to carry out sales of securities via the settlement of foreign currency and its transfer to depository institutions abroad. In this connection, in order to carry out any outflow of funds, the entity must:

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• request the prior approval of the Central Bank; or

• rely on an affidavit stating that the client did not carry out neither sales of securities via the settlement of foreign currency nor its transfer to foreign depository entities on the day that access to the foreign exchange market was requested and within 90 days prior to such request, as well as that the customer undertakes not to carry out such transactions from the date access to the foreign exchange market is requested and for the subsequent 90 calendar days.

The Central Bank Communication “A” 7,030 also establishes the prior approval of the Central Bank to carry out any outflow of funds through the foreign exchange market from May 29, 2020 onwards, with some exceptions.

In addition, Communication “A” 7,030, as amended, established the prior approval of the Central Bank for certain outflow of funds through the foreign exchange market, unless the entity has an affidavit from the client stating that at the time of access to the foreign exchange market:

• All of its local foreign currency holdings are deposited in accounts in financial institutions and that it did not have liquid external assets available at the beginning of the day that access to the foreign exchange market is requested for a higher amount equivalent to US$100,000 (with some exceptions, expressly provided for by the regulation).

• Undertakes to settle in pesos through the foreign exchange market, within five working days of its availability, those funds received abroad resulting from the collection of loans granted to third parties, the collection of a term deposit or the sale of any type of asset, when the asset has been acquired, the deposit constituted or the loan granted after May 28, 2020.

In addition to the above, by means of Communication “A” 7327, the Central Bank established that, as of July 12, 2021, in order for residents to be granted access to the foreign exchange market, it will be required (in addition to the preexisting conditions), that: (i) on the same day that such access is required and within the previous 90 days, such local resident has not exchanged securities for other foreign assets (in addition to the already existing requirement of not having sold securities with settlement in foreign currency or transferred them to depository institutions abroad during the same period); and (ii) for legal entities, to submit a sworn statement informing (a) a list of the persons or legal entities that directly control the client; and (b) that within the previous 90 days (or since July 12, 2021, in the event that 90 days have not yet elapsed since that date), the legal entity has not delivered in the country any funds in local currency or other liquid local assets to any of the aforementioned persons (except for those directly associated with usual transactions involving the acquisition of goods and/or services). Alternatively, the requirement set forth in (b) may be considered fulfilled if the legal entity submits a sworn statement executed by each of those persons exercising direct control stating that, during the same period, no sales of securities with settlement in foreign currency, or exchanges of securities for other external assets, or transfers thereof to depository institutions abroad, have been made.

On October 5, 2021, by means of General Resolution 907/21, a limit on the sale of securities which are denominated in U.S. dollars and issued under local law was established at the end of each week for those transactions that had a concurrence of tenders received with a priority of price and time. This limit may not exceed the amount of fifty thousand nominal values settled. Plus, it was also established as prior condition for those transactions that the orders may only be given if no sales have been made with foreign settlement in the previous 30 days, and a commit not to do so within 30 subsequent calendar days.

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Securities trading

Entities authorized to operate on exchanges may not purchase securities in the secondary market with settlement in foreign currency or use holdings of their general exchange position for payments to local suppliers.

Pursuant to Communication “A” 7001, as amended by Communication “A” 7,030, the BCRA established certain restrictions to carry out sales of securities via the settlement of foreign currency and its transfer to depository institutions abroad. In this connection, in order to carry out any outflow of funds, the entity must:

• request the prior approval of the BCRA; or

• rely on an affidavit stating that the client did not carry out neither sales of securities via the settlement of foreign currency nor its transfer to foreign depository entities on the day that access to the foreign exchange market was requested and within 90 days prior to such request, as well as that the customer undertakes not to carry out such transactions from the date access to the foreign exchange market is requested and for the subsequent 90 calendar days.

Central Bank Communication “A” 7,106 established that non-residents will not be able to arrange sales of securities with settlement in foreign currency, except for sales of securities that have been acquired in Argentina with liquidation in foreign currency from September 16, 2020 and have remained in the non-resident’s portfolio for a period not less than a year.

On April 21, 2023, the BCRA issued Communications “A” 7746 and 7747 which provides for certain modifications to the rules of access to the MULC for the payment of services, payment of interest to related companies abroad that correspond to imports of goods and/or services and/or financial loans.

In the case of transactions with securities, the term of 90 calendar days prior and subsequent to the access to the foreign exchange market without having carried out transactions of this nature, will only apply to securities issued under Argentine law. In the remaining cases the term will be increased to 180 calendar days. This term will be considered for transactions carried out as from April 21, 2023.

On July 8, 2021, the CNV, approved General Resolution 895/2021, to increase the minimum holding periods for the settlement of securities against foreign currency and in foreign jurisdiction. Said General Resolution does not incorporate modifications for the settlement of securities against local currency.

The minimum holding period, locally known as “Parking Period”, for securities in the local custodian to be applied to the settlement of transactions in foreign currency and in foreign jurisdiction (i.e., settlement against “Dollar Cable” in a foreign account) was set to two (2) business days. This Parking Period does not apply in the case of purchases of securities with settlement in foreign currency and in a foreign jurisdiction.

In the case of sales of securities with settlement in foreign currency, but in local jurisdiction (i.e., settlement against a MEP transfer to a local account), the Parking Period remains one (1) business day. This Parking Period shall not apply in the case of purchases of securities settling in foreign currency.

The Parking Period prior to settlement against foreign currency and in foreign jurisdiction (i.e. settlement against “Dollar Cable” in a foreign account) for locally credited securities from foreign depositories (i.e. acquired from foreign agents) has also been set to two (2) business days. In the case of transactions with settlement in foreign currency and in local jurisdiction (i.e., settlement against a MEP transfer to a local account), the Parking Period remains at 1 business day.

Finally, the CNV also modified the maximum limits for weekly transactions in sovereign securities issued by the Argentine Republic for each principal sub-account in the time-priority bidding segment (BYMA), which prior to the entry into force of the General Resolution was one hundred thousand (100,000) nominal amounts (only for securities issued under local law). According to the new General Resolution, the limit was split into (i) fifty thousand (50,000) nominals for securities issued under local law, purchased with settlement in such currency and jurisdiction, and (ii) fifty thousand (50,000) nominals for securities issued under foreign law. These limits continue not to apply to wholesale transactions (MAE/SENEBI).

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Nevertheless, this would not prevent non-residents from transferring abroad securities acquired in the country, and perform their sales abroad, in which case they would take into account the minimum holding term (or “parking”) mentioned below.

In addition, the above-mentioned Communication established that transactions of securities arranged abroad and securities acquired abroad may not be settled in pesos in the country.

Nevertheless, we understand that the transactions of acquiring securities in pesos in the country with funds from abroad would not be forbidden, to the extent that the transaction is not documented abroad.

Foreign Exchange Criminal Regime

Any operation that does not comply with the provisions of the foreign exchange controls is reached by the Foreign Exchange Criminal Regime.

Money Laundering

Law No. 25,246, as amended, categorizes money laundering as a crime, defining it as the exchange, transfer, management, sale or any other use of money or other assets obtained through a crime, by a person who did not take part in such original crime, with the potential result that such original assets (or new assets resulting from such original assets) appear as if obtained through legitimate means; provided that the aggregate value of the assets involved exceeds in the aggregate (through one or more related transactions) Ps.50,000.

In addition, Law No. 25,246 created a financial information unit (the “Financial Information Unit”), which is charged with the handling and the transmission of information in order to prevent the laundering of assets originating from:

• Crimes related to illegal trafficking and commercialization of narcotics;

• Crimes related to arms trafficking;

• Crimes related to the activities of an illegal association as defined in Article 210 bis* of the Penal Code;

• Illegal acts committed by illegal associations organized to commit crimes with political or racial objectives;

• Crimes of fraud against the Public Administration;

• Crimes against the Public Administration;

• Crimes of underage prostitution and child pornography; and

• Crimes related to terrorism financing.

Law No. 25,246 assigns information and control duties to certain private sector entities, such as banks, agents, stock exchanges and insurance companies, according to the regulations of the Financial Information Unit, and for financial entities, the BCRA. These regulations apply to many Argentine companies. These obligations consist mainly of maintaining internal policies and procedures aimed at preventing money laundering and financing of terrorism, especially through the application of “know your customer” policies.

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On May 8, 2005, the CNV enacted Resolution No. 554, which provides that broker-dealers and other intermediaries that are subject to its supervision can only take part in securities transactions if they are ordered or executed by parties that are registered or domiciled in jurisdictions that are not included in the list of tax havens included in Decree No. 1,344/98. Furthermore, the Resolution provides that securities transactions made by parties registered or domiciled in jurisdictions that are not included in such list, but that act as intermediaries of securities markets under the supervision of an agency similar to the CNV, are allowed only if such agency has signed a memorandum of mutual understanding with the CNV. Regarding the listed companies under the supervision of the CNV, Resolution No. 554 states that they shall identify any entity or individual (whether or not a shareholder at that time) that makes a capital contribution or a significant loan, and comply with the same obligations established in the previous paragraph for the brokers-dealers and other intermediaries.

Pursuant to Decree 360/2016, dated February 16, 2016, the Government created the “National Coordination Program for Combating Money Laundering and Terrorist Financing” within the purview of the Ministry of Justice and Human Rights. Its purpose is to rearrange, coordinate and strengthen the anti-money laundering and anti-terrorist financing system at the national level, in light of the actual risks that could impact the Argentine territory and the global requirements to be met under the scope of the obligations and international recommendations of the United Nations and Financial Action Task Force standards.

Moreover, Law No. 27,260 introduced certain tax modifications and a new regime for residents to disclose undeclared assets, and also established that the Financial Information Unit would now be within the purview of the Ministry of Economy and Finance.

On December 22, 2017, the BCRA enacted Communication “A” 6399 by means of which it abrogated item 1.3 of the regulations regarding “Anti-Money Laundering, Terrorism Financing and other illegal activities” which regulated the obligation of financial institutions and foreign exchange agencies to maintain certain databases, as of January 1, 2018.

The abrogated regulations established the obligation for financial institutions and foreign exchange agencies subject to the BCRA’s regulation to maintain databases regarding client operations.

In turn, Decree No. 27/2018, dated January 10, 2018, amended Law No. 25,246 related to the requirements imposed upon obliged subjects (“Obliged Subjects”), the management of their client’s information and the information required for “know your client” purposes. Such decree now requires Obliged Subjects to refrain from revealing any investigations carried out in compliance with Law No. 25,246 to their clients and/or any third parties.

On January 11, 2017, the Financial Information Unit published Resolution No. 4/2017, which established that special due diligence measures must be applied for identifying foreign and domestic investors (who shall comply with the requirements therein set forth to qualify as such) in the Republic of Argentina upon requesting the opening of special investment accounts. Since October 2018, the BCRA established an exchange rate band. The band in which the BCRA would not intervene was initially defined between Ps.34 and 44 per U.S. dollar, which will be adjusted upwards on a monthly basis. The BCRA will allow the free floating of the currency within this band. The intention of the BCRA is to avoid excessive fluctuations of the exchange rate.

Subsequently, the Financial Information Unit published Resolution No. 30-E/17, effective as of September 15, 2017, which repealed Resolution No. 121 and established new guidelines to be followed by financial and securities institutions in their capacity as parties legally obliged to provide financial information under the Anti-Money Laundering Law, based on the revised recommendations of the Financial Action Task Force for 2012.

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These amendments facilitate compliance of the requirements imposed upon the Obliged Subjects and continue the migration of the system towards a risk-based approach.

Resolution No. 30-E/17 determines the minimum compliance elements that must be included in a system for the prevention of money laundering and terrorist financing, such as the process of customer due diligence, training programs, operations monitoring, reporting of suspicious operations and rules applicable in cases of non-compliance, among others.

The Financial Information Unit published Resolution No. 21/2018 which states that reporting parties under Resolution No. 229/2014 of the Financial Information Unit (mainly the BCRA and the CNV) must evaluate their risks and adopt measures to mitigate them, in order to prevent money laundering as efficiently as possible. Within this framework, individuals are enabled to implement reputable technological platforms which allow carrying out long-distance procedures without the need to present documentation in person.

E. Taxation

General

The following general summary of the main tax consequences in Argentina and the United States relating to the, ownership and disposition of securities issued by us is based on the tax laws of Argentina, the United States and regulations thereunder (as applicable) as in effect on the date hereof, each subject to any changes that may come into effect after such date under the Argentine and United States laws and regulations (as applicable) as may become effective subsequently to such date, possibly with retroactive effect.

Even though this summary is considered to constitute an appropriate interpretation of the effective Argentine tax laws and United States federal income tax laws as of the date hereof, no assurance may be given that the courts or tax authorities in charge of application of such laws will agree to this interpretation. Furthermore, it should be noted that there have been many changes in Argentine tax laws and United States tax laws in the past and in particular in recent years, and that such laws may be subject to restatements, revocation of exemptions, reestablishment of taxes and other changes.

Prospective investors should consult their own tax advisors as to the Argentine tax consequences and United States federal income tax consequences of the purchase, ownership and disposition of our securities, including, the effect of any foreign, state or local tax laws.

Argentine Taxes

Income Tax

Law No. 27,430, enacted on December 27, 2017 and published in the Official Gazette on December 29, 2017, had introduced several amendments to Income Tax Law No. 20,628, among others, a corporate tax rate reduction in two phases. For fiscal years beginning on or after January 1, 2018 until December 31, 2019, there had been a reduction of the tax rate from 35% to 30%. Beginning on or after January 1, 2020 the tax rate would have been further reduced to 25%. Additionally, a withholding of 7% or 13% had been established for the fiscal years mentioned above, on the dividends distributed by local entities in favor of their shareholders provided they are resident individuals or undivided estates, or are foreign beneficiaries.

On June 16, 2021, Law 27,630 was enacted and published in the Official Gazette. This law increases corporate income tax rates for tax years beginning January 1, 2021, and onwards. The new law increases tax rates by replacing the fixed tax rate with a progressive tax scale. It also extends the 7% withholding tax rate currently in force to dividends from profits accrued in tax years beginning January 1, 2021, and thereafter.

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Taxation on Dividends

In view of the last amendments introduced to the Income Tax Law by virtue of the Tax Reform, as of fiscal years beginning on January 1, 2018, the taxation applicable to dividends distributed from Argentine companies would be as follows, as amended by the Solidarity Law:

Dividends originated from profits obtained during fiscal years 2019, 2020 and 2021: dividends on Argentine shares paid to Argentine individuals and/or non-residents (“Foreign Beneficiaries”) are subject to a 7% income tax withholding on the amount of such dividends (“Dividend Tax”).

Dividends originated from profits obtained during fiscal year 2021 onward: the tax rate is raised to 7%.

For Argentine individuals not registered before the Federal Administration of Public Revenues (Administración Federal de Ingresos Públicos) as payers of income tax and foreign beneficiaries, the Dividend Tax withholding will be considered as a unique and final payment. In addition, under the Tax Reform, rules are created that regulate and limit the possibility to offset gains derived from the distribution of dividends with losses generated in other operations.

If dividends are distributed to Argentine Entities as defined below, no Dividend Tax should apply.

However, Law No. 27,451, published in the Official Gazette on December 23, 2019, suspended, until fiscal years starting on January 1st, 2021, the application of the withholding tax at a 13% rate on payment of dividends and profit distribution, and reestablished the 7% rate for this withholding tax.

Capital Gains Tax

Resident individuals

Capital gains obtained by resident individuals or undivided estates situated in Argentina from the sale or disposition of common shares and other securities are subject to income tax at a 15% rate on net income, unless such securities were traded in stock exchange under the supervision of the CNV, in which case an exemption applies.

Losses arising from the sale, exchange or other disposition of common shares or ADSs can be applied only to offset such capital gains arising from the sale, exchange or other disposition of these securities, for a five‑year carryover period.

Foreign beneficiaries

Capital gains of Argentine source (as it is the case of both our ADSs and shares) obtained by non-Argentine individuals or non-Argentine entities from the sale, exchange or other disposition of shares are subject to income tax at a 15% rate on the net capital gain or at a 13.5% rate on the gross price at the seller’s election. Notwithstanding, Law No. 27,430 established an exemption for foreign beneficiaries participating in the sale of publicly traded shares traded in stock exchanges under the supervision of the CNV. Said Law also established an exemption for capital gains derived from the sale, exchange or other disposition of share certificates issued abroad that represent shares issued by Argentine companies (i.e. ADRs). The exemptions will apply only if the foreign beneficiaries do not reside in, and the funds do not arise from, “non-cooperating” jurisdictions for tax transparency purposes.

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The sale of an equity interest in a foreign entity could represent a taxable indirect transfer of Argentine assets (including shares), if (i) the value of the Argentine assets exceed 30% of the transaction’s overall value, and (ii) the equity interest sold (in the foreign entity) exceeds 10%. The tax will also be due if any of these thresholds were met during the twelve month period prior to the sale.

The applicable rate is generally 15% on the net capital gain or at a 13.5% rate on the gross price at the seller’s election, of the proportional value that corresponds to the Argentine assets.

The indirect transfer of Argentine assets within the same economic group would also not trigger taxation, provided the requirements set by regulations have been met.

Argentine entities

Capital gains obtained in tax years beginning from January 1, 2022 by Argentine entities (in general entities organized or incorporated under Argentine law, certain traders and intermediaries, local branches of non-Argentine entities, sole proprietorships and individuals carrying on certain commercial activities in Argentina) derived from the sale, exchange or other disposition of shares or ADSs are subject to the following tiered structure of corporate income tax rates for different brackets of earnings:

Annual taxable income (ARS)	Tax due on lower limit (ARS)	Marginal rate on the excess of the lower limit
0 to 7.60 million	ARS 0	25%
Over 7.60 million to 76.04 million	ARS 1.90 million	30%
Over 76.04 million	ARS 22.43 million	35%

Losses arising from the sale, exchange or other disposition of shares or ADSs can be applied only to offset such capital gains arising from the sale, exchange or other disposition of these securities, for a five-year carryover period.

WE RECOMMEND PROSPECTIVE INVESTORS TO CONSULT THEIR OWN TAX ADVISOR REGARDING THE PARTICULAR TAX CONSEQUENCES CONCERNING THE SALE OR OTHER DISPOSITIONS OF SHARES AND ADSs.

Value Added Tax (“VAT”)

The sale, exchange or other disposition of our ADSs or common shares and the distribution of dividends are exempted from VAT.

Personal Assets Tax

Argentine entities, like us, are subject to the personal assets tax corresponding to Argentine individuals and Foreign Beneficiaries (be they legal entities or individuals) for the holding of company shares at December 31 of each year.

Pursuant to Law No. 27,541, as of December 31, 2019, the rate is 0.50% and is levied on the proportional net worth value (“valor patrimonial proporcional”), of the shares as per the Argentine entity’s last financial statements prepared under Argentine GAAP.

Pursuant to the Personal Assets Tax Law, the Argentine company is entitled to seek reimbursement of such paid tax from the applicable Argentine domiciled individuals and/or foreign domiciled shareholders.

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Tax on Credits and Debits on Bank Accounts

Law No. 25,413, as amended and regulated by Law No. 25,453, established a tax, with certain exceptions, levied on debits and credits of any nature on bank accounts held at Argentine financial institutions, except for those specifically exempted pursuant to legal provisions and regulations thereof. The general tax rate is 0.6% for each debit and credit (although in certain cases an increased rate of 1.2% and a reduced rate of 0.075% may apply).

Certain transfers of money or cash movements through other mechanisms may also trigger application of this tax. In general, the financial institutions involved act as tax collection and tax calculation agents.

Decree No. 409/2018 established that as of January 1st, 2018, 33% of the tax paid on credits and debits levied at the 0.6% general tax rate and 1.2% tax rate, and 20% of the tax paid on transactions levied at the lesser tax rate, will be considered as a payment on account of income tax, taxes on presumed minimum income or the special contribution on cooperatives capital by the bank account holders. The exceeding amount will not be subject to compensation with other taxes or transfer in favor of third parties; however, it can be carried forward to other fiscal periods of the above-mentioned taxes.

This tax has certain exemptions; as an example, debits and credits in banking accounts opened by foreign legal entities in accordance with BCRA Communication “A” 3250 and used exclusively for the purpose of making financial investments in Argentina are exempted from this tax is accordance with section 10, paragraph s) of Decree No. 380/2001. Likewise, Law No.27,264 established that the Tax on Credits and Debits on Bank Accounts that had actually been deposited may be computed in a 100% as payment on account of the income tax by companies that are considered “micro” and “small” and in 50% by manufacturing industries considered “medium -trench 1-” under the terms of article 1 of Law No. 25,300 and its complementary regulations. In case securities’ holders receive payments in local bank checking accounts, such tax may apply.

Pursuant to Law No. 27,432, dated December 29, 2017, this tax will be applied until December 31, 2022. Moreover, according to this law, the Government may provide that the percentage of this tax that on the effective date of this law (i.e. December 30, 2017) is not computable as payment on account of income tax, it is progressively reduced by up to 20% per year as of January 1, 2018, and it can be established that, in 2022, it can be completely calculated as a payment on account of the income tax.

Turnover Tax

Turnover tax is a local tax levied on gross income earned from an activity during the year and it is applied by each provincial jurisdiction or the City of Buenos Aires.  Any investors regularly engaged in activities, or presumed to be engaged in activities, in any provincial jurisdiction or in the City of Buenos Aires where they receive revenues from interest arising from holding notes, or from their sale or conveyance, could be subject to the turnover tax at rates that vary according to the specific laws of each Argentine province and of the City of Buenos Aires, unless an exemption applies.

There is a system of Collection and Control over Credits on Bank Accounts (“SIRCREB”) that enables the compliance of the turnover tax collection’s regimes, applicable over the amounts credited in Argentine bank accounts.  The regimes vary according to the specific laws of each Argentine province. The aliquots to apply depend on each one of the treasuries with a range that can currently reach 5%.

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Buenos Aires Tax Code, Section 180(1), third paragraph, sets forth that revenues from any transaction on notes issued in accordance with Law No. 23,576, the interest collected and updates accrued and the selling price in case of a transfer, shall be exempt provided the income tax exemption is applicable.

The Province of Buenos Aires Tax Code sets forth a similar exemption in Section 207 (c), second paragraph.

Considering the autonomous authority vested in each provincial jurisdiction in connection with tax matters, any potential effects derived from these transactions must be analyzed, in addition to the tax treatment established by other provincial jurisdictions. Potential investors must consider the effects of the turnover tax and the SIRCREB regime depending on the local jurisdictions involved. Also, as certain jurisdictions have excluded the application of these regimes on certain financial transactions, holders shall verify the existence of any exclusion to these regimes in accordance with the jurisdiction involved.

Stamp Tax

The stamp tax is a local tax that is generally levied on the consummation of onerous transactions executed within a certain provincial jurisdiction or outside a certain provincial jurisdiction but with effects in such jurisdiction.

Notwithstanding the fact that the stamp tax is a local tax, for Buenos Aires City, the acts, contracts and transactions, including money delivery or receipt transactions, related to the issuance, subscription, placement and transfer of notes, issued pursuant to the Negotiable Obligations Law regime are exempted from application of this tax.  This exemption shall include the creation of any real or personal guarantees in favor of investors or third-parties guaranteeing the issuance, either prior to, simultaneous with or subsequently to such issuance.

This exemption also covers security rights related to issuances. However, this exemption is forfeited if, within a 90-calendar days term, the relevant authorization is not requested for the public offering of such securities before the CNV.

The acts and/or instruments related to the trading of shares and other securities duly authorized for public offering by the CNV are exempted from application of stamp tax in the City of Buenos Aires.  This exemption is also ineffective if the circumstances mentioned in the last sentence of the previous paragraph occur.

In turn, in the Province of Buenos Aires, any acts, contracts, transactions, including money delivery or receipt transactions, related to the issuance, subscription, placement and transfer of notes issued pursuant to the Negotiable Obligations Law regime and Law No. 23,962 are exempted from application of this tax.  This exemption shall include the creation of any real or personal guarantees in favor of investors or third-parties guaranteeing the issuance, either prior to, simultaneous with or subsequently to such issuance.

Considering the autonomous authority vested in each provincial jurisdiction in connection with tax matters, any potential effects derived from these transactions must be analyzed, in addition to the tax treatment established by the other provincial jurisdictions.  Potential investors must consider the stamp tax impact depending on the local jurisdictions involved.

Transfer Taxes

The Province of Buenos Aires passed Law No. 14,044, approved on September 23, 2009 and published in the Argentine Official Gazette on October 16, 2009, whereby it imposed a Tax on Gratuitous Transfer of Assets (“TGTA”), effective as of January 1, 2011.

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The basic aspects of the TGTA are:

TGTA is applicable to any enrichment resulting from gratuitous transfers, including:  inheritances, legacies, donations anticipated, or any other event that implies a gratuitous monetary enrichment.

The tax is payable by individuals and legal entities that are beneficiaries of a gratuitous transfer of assets.

For taxpayers domiciled in the Province of Buenos Aires, the tax is levied on the total amount of the gratuitous enrichment, in respect of property situated both in and outside of the Province of Buenos Aires.  Instead, for taxpayers domiciled outside of the Province of Buenos Aires, the tax is levied only on the gratuitous enrichment resulting from the transmission of assets located within the Province of Buenos Aires.

The following types of property, which may be freely transferred, are deemed situated in the Province of Buenos Aires (i) securities and shares of stock, notes, membership or equity interests and other negotiable instruments representing capital stock, issued by governmental or private entities and companies domiciled in the Province of Buenos Aires; (ii) securities, shares of stock and other negotiable instruments issued by private entities or companies domiciled in a different jurisdiction that were physically situated in the Province of Buenos Aires at the time of their transmission; and (iii) securities, shares of stock and other negotiable instruments representing capital stock or its equivalent issued by entities or companies domiciled in another jurisdiction which are also physically situated in another jurisdiction, in proportion to the issuer’s assets situated in the Province of Buenos Aires.

The gratuitous transfer of assets is exempt from tax when their aggregate value, excluding deductions, exemptions and exclusions, is equal to or lower than Ps.269,000 and it rises to Ps.1,120,000 when the transfer is done between parents, children and spouses.

Step‑up rates from 1.6026% to 8.7840% have been established, based on the degree of kinship and taxable base involved.

The Province of Entre Ríos, pursuant to provincial Law No. 10,553, dated December 13, 2017, has revoked its provincial TGTA stated by virtue of Law No. 10,197.

As for the existence of the TGTA in other provinces, potential investors must analyze the tax consequences according to the jurisdictions involved in the specific case.

Court Taxes

In the event that it becomes necessary to institute legal actions in relation to our securities before a federal court in Argentina or the courts sitting in the City of Buenos Aires, a court tax will be imposed on the amount of any claim (currently at a rate of 3.0%). Certain court and other taxes could be imposed on the amount of any claim brought before the courts of the relevant province.

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Treaties to Avoid Double Taxation

Argentina has signed tax treaties for the avoidance of double taxation with Australia, Belgium, Bolivia, Brazil, Canada, Chile, Denmark, Finland, France, Germany, Italy, Mexico, Norway, Qatar, Russia, Spain, Sweden, Switzerland, The Netherlands, United Arab Emirates, United Kingdom, and Uruguay (through an information exchange treaty that contains clauses for avoidance of double taxation). In addition, Argentina has signed tax treaties with Turkey, Luxembourg, Japan, Austria and China, but they are still pending approval by the Argentine Congress. In turn, tax treaties are being negotiated with Colombia and Israel, and amendments to the current tax treaty with France. There is currently an agreement between Argentina and the United States on the exchange of Country-by-Country Reports, but there is no tax treaty or convention in effect between both countries. It is not clear when, if ever, a treaty will be ratified or entered into effect. As a result, the Argentine tax consequences described in this section will apply, without modification, to a holder of our common shares or ADSs that is a U.S. resident. Foreign shareholders located in certain jurisdictions with a tax treaty in force with Argentina may be exempted from the payment of the personal asset tax.

Inflow of Funds from Non‑Cooperative Jurisdictions

Non-cooperative jurisdictions are those countries or jurisdictions that do not have in force with the Government an agreement for the exchange of information on tax matters or a treaty to avoid international double taxation with a broad clause for the exchange of information.  Likewise, those countries that, having an agreement of this type in force, do not effectively comply with the exchange of information will be considered non-cooperative. The aforementioned treaties and agreements must comply with international standards of transparency and exchange of information on fiscal matters to which the Argentine Republic has committed itself. After the tax reform the white list system in force was replaced by a black list system. In this system, the Executive Branch would have to prepare and update a list of the countries considered as non-cooperative based on the aforementioned criteria. As of today, the United States is considered a cooperating country.

According to the legal assumption established by Law No. 11,683 Section 18.1 as amended, incoming funds from non-cooperative jurisdictions are considered unjustified net worth increases for the local receiver.

Unjustified net worth increases are subject to the following taxes:

• Income tax would be assessed on 110% of the amount of funds transferred;

• VAT would be assessed on 110% of the amount of funds transferred. Even though the concept “income arising from” is not clear, it could be construed as any fund transfer;

• from an account in a non-cooperative jurisdiction, or from a bank account opened outside of a non-cooperative jurisdiction but owned by an entity located in a non-cooperative jurisdiction; or

• to a bank account located in Argentina or to a bank account opened outside of Argentina but owned by an Argentina tax resident.

Notwithstanding the above, the Law provides that the Federal Administration of Public Revenues can accept those funds that derived from activities genuinely performed by an Argentine taxpayer, or by a third party in said jurisdiction.

With respect to the application of the above-mentioned legal presumption on incoming funds from jurisdictions considered as low or null tax jurisdictions (defined under section 15.3 of the Argentine Income Tax Law) further clarifications are expected to be issued by the implementing decree of the Tax Reform.

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THE ABOVE SUMMARY DOES NOT REPRESENT A FULL ANALYSIS OF ALL THE TAX CONSEQUENCES AND DOES NOT ADDRESS ALL OF THE ARGENTINE TAX CONSEQUENCES THAT MAY BE APPLICABLE DERIVED FROM THE OWNERSHIP OF NEGOTIABLE OBLIGATIONS.  POTENTIAL HOLDERS AND BUYERS SHOULD CONSULT THEIR OWN TAX ADVISERS REGARDING THEIR PARTICULAR TAX CONSEQUENCES. IT DOES NOT PURPORT TO BE A COMPREHENSIVE DESCRIPTION OF ALL THE ARGENTINE TAX CONSIDERATIONS THAT MAY BE RELEVANT TO A DECISION TO PURCHASE, OWN OR DISPOSE OUR SHARES. IN PARTICULAR, THIS SUMMARY DOES NOT DESCRIBE ANY TAX CONSEQUENCES ARISING UNDER THE LAWS OF ANY STATE, LOCALITY, MUNICIPALITY OR TAXING JURISDICTION OTHER THAN CERTAIN FEDERAL LAWS OF ARGENTINA.

United States Taxes

General. This following discussion is a summary of U.S. federal income tax consequences generally applicable to a U.S. holder (as defined below) who holds our Class B Shares or ADSs. It applies to a U.S. holder only if such holder holds our Class B Shares or ADSs as “capital assets” within the meaning of the Internal Revenue Code of 1986, as amended (the “Code”) and is not a member of a special class of holders subject to special rules, including: a dealer in securities; a trader in securities that elects to use a mark-to-market method of accounting for his or her securities holdings; a tax-exempt organization; a life insurance company; a person liable for alternative minimum tax; a person that actually or constructively owns 10% or more of the voting power or value of our aggregate shares outstanding; a person that holds Class B Shares or ADSs as part of a hedging or straddle or conversion transaction; a person that purchases or sells Class B Shares or ADSs as part of a wash sale for tax purposes; a partnership (or other entity or arrangement treated as a partnership for U.S. federal income tax purposes) and partners or members therein; or a person whose functional currency is not the U.S. dollar.

This discussion is based on the Code, its legislative history, existing and proposed regulations, published rulings and court decisions, and the laws of Argentina all as currently in effect. These laws are subject to change, possibly on a retroactive basis. In addition, this section is based in part upon the assumption that each obligation in the Deposit Agreement and any related agreement will be performed in accordance with its terms.

If a partnership (or other entity or arrangement treated as a partnership for U.S. federal income tax purposes) holds Class B Shares or ADSs, the U.S. federal income tax treatment of a partner will generally depend on the status of the partner and the tax treatment of the partnership. A partner in a partnership holding Class B Shares or ADSs should consult its tax advisor with regard to the U.S. federal income tax treatment of an investment in Class B Shares or ADSs.

A holder is a U.S. holder if such holder is a beneficial owner of Class B Shares or ADSs and such holder is: a citizen or resident of the United States; a domestic corporation or other entity taxable as such; an estate whose income is subject to U.S. federal income tax regardless of its source; or a trust, if a United States court can exercise primary supervision over the trust’s administration and one or more United States persons are authorized to control all substantial decisions of the trust.

In general, and taking into account the earlier assumptions, for U.S. federal income tax purposes, a holder of ADRs evidencing ADSs will be treated as the owner of the underlying Class B Shares represented by those ADSs, and exchanges of Class B Shares for ADRs, and ADRs for Class B Shares, will not be subject to U.S. federal income tax.

This discussion does not generally address any aspects of U.S. taxation other than federal income taxation. Holders of Class B Shares or ADSs are urged to consult their tax advisors regarding the U.S. federal, state and local tax consequences of owning and disposing of the Class B Shares or ADSs in their particular circumstances.

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Taxation of Dividends. Under the United States federal income tax laws, and subject to the passive foreign investment company (“PFIC”) rules discussed below, a U.S. holder must include in his or her gross income the gross amount of any dividend that we pay out of our current or accumulated earnings and profits (as determined for U.S. federal income tax purposes). If the holder is a non-corporate U.S. holder, dividends that constitute qualified dividend income will be taxable at the preferential rates applicable to long-term capital gains; provided that the Class B Shares or ADSs are held for more than 60 days during the 121-day period beginning 60 days before the ex-dividend date and certain other holding period requirements are met. Provided that we are not a PFIC, for the year in which a dividend is paid or the preceding taxable year, dividends that are paid with respect to the ADSs that are readily tradable on an established securities market in the United States are qualified dividend income. Under this rule, we expect that the dividends we pay with respect to the ADSs will be qualified dividend income. Because the Class B Shares are not readily tradable on an established securities market in the United States, it is unclear whether dividends paid with respect to the Class B Shares will also be qualified dividend income.

The holder must include any Argentine tax withheld from the dividend payment in this gross amount even though the holder does not in fact receive it. The holder must include the gross amount of dividends in income when the holder, in the case of Class B Shares, or the depositary, in the case of ADSs, receives the dividend, actually or constructively. The dividend will not be eligible for the dividends-received deduction generally allowed to U.S. corporations in respect of dividends received from other U.S. corporations. Distributions in excess of current and accumulated earnings and profits, as determined for U.S. federal income tax purposes, will be treated as a non-taxable return of capital to the extent of a holder’s basis in the Class B Shares or ADSs and thereafter as capital gain.

The amount of the dividend distribution that a holder must include in his or her income will be the U.S. dollar value of the peso payments made, determined at the spot peso/U.S. dollar rate on the date such dividend distribution is includible in such holder’s income, regardless of whether the payment is in fact converted into U.S. dollars. Generally, any gain or loss resulting from currency exchange fluctuations during the period from the date a holder includes the dividend payment in income to the date such payment is converted into U.S. dollars will be treated as ordinary income or loss and will not be eligible for the special tax rate applicable to qualified dividend income. Such gain or loss will generally be income or loss from sources within the United States for foreign tax credit limitation purposes.

For foreign tax credit purposes, the dividend will generally be income from sources outside the United States. Dividends will, depending on the holder’s circumstances, generally be either “passive” or “general” income, for purposes of computing the foreign tax credit allowable to the holder. Subject to certain limitations, the Argentine tax withheld and paid over to Argentina will generally be creditable or deductible against your U.S. federal income tax liability. Special rules apply in determining the foreign tax credit limitation with respect to dividends that are subject to the preferential tax rates.

However, it is likely that no U.S. foreign tax credit will be allowed to U.S. holders of Class B Shares or ADSs in respect of any personal property or similar tax imposed by Argentina (or any taxing authority thereof or therein) (for example, if such tax is not treated as an income tax for U.S. federal income tax purposes). The calculation of foreign tax credits and, in the case of a U.S. holder that elects to deduct foreign taxes, the availability of deductions, involve the application of complex rules that depend on a U.S. holder’s particular circumstances. All U.S. holders should consult their own tax advisors regarding the creditability or deductibility of such taxes.

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Taxation of Capital Gains. Subject to the PFIC rules discussed below, a U.S. holder that sells or otherwise disposes of Class B Shares or ADSs will recognize gain or loss for U.S. federal income tax purposes in an amount equal to the difference between the U.S. dollar value of the amount realized and his or her tax basis (determined in U.S. dollars) in such Class B Shares or ADSs. Capital gain of a non-corporate U.S. holder is generally taxed at preferential rates where the holder has a holding period greater than one year. The gain or loss generally will be income or loss from sources within the U.S. for foreign tax credit limitation purposes.

As discussed in the previous paragraph, it is possible that a U.S. holder who sells or purchases the Class B Shares or ADSs may be subject to Argentine tax upon such sale or acquisition. If the seller is legally liable for the tax and the seller pays this tax, then the seller should be able to claim a foreign tax credit for U.S. federal income tax purposes in an amount equal to the amount of the tax, subject to generally applicable limitations. However, because the gain from a sale or other disposition of Class B Shares or ADSs will be U.S. source income, such seller would need a sufficient amount of other foreign source income that is untaxed, or that is taxed at a tax rate that is sufficiently lower than the U.S. tax rate applicable to such seller, in order to be able to claim this foreign tax credit. Additionally, if an Argentine tax is withheld on the sale or other disposition of Class B Shares or ADSs, then the seller must include the amount of such tax withheld in the amount realized upon the sale or disposition, even though the seller does not in fact receive it. If the purchaser is legally liable for the tax, then the purchaser will likely not be entitled to receive any tax credit in the United States in respect of the payment of any such taxes.

PFIC Rules. In general, a non-U.S. corporation will be classified as a “passive foreign investment company,” or PFIC, for U.S. federal income tax purposes, if either (i) 75% or more of its gross income consists of certain types of “passive” income or (ii) 50% or more of the fair market value of its assets (determined on the basis of a quarterly average) produce or are held for the production of passive income. For this purpose, cash is categorized as a passive asset. We will be treated as owning our proportionate share of the assets and earning our proportionate share of the income of any other corporation in which we own, directly or indirectly, 25% or more (by value) of the shares. We do not believe that we were a PFIC for the taxable year ended December 31, 2017. We do not anticipate being a PFIC for our current taxable year, although we can make no assurances in this regard. Our status as a PFIC in any year depends on our assets and activities in that year. We have no reason to believe that our assets or activities will change in a manner that would cause us to be classified as a PFIC for the current taxable year or for any future year, however this is a factual determination that is made annually and thus may be subject to change.

If we were to be treated as a PFIC, unless a U.S. holder makes a valid election to be taxed annually on a mark-to-market basis with respect to the Class B Shares or ADSs, gain realized on the sale or other disposition of the shares or ADSs would in general not be treated as capital gain. Instead, the U.S. holder would be treated as if he had realized such gain and certain “excess distributions” ratably over the holding period for the shares or ADSs and would be taxed at the highest tax rate in effect for each such year to which the gain was allocated, together with an interest charge in respect of the tax attributable to each such year. With certain exceptions, Class B Shares or ADSs will be treated as stock in a PFIC if we were a PFIC at any time during the holding period of a U.S. holder. In addition, dividends received from us will not be eligible for the special tax rates applicable to qualified dividend income if we are treated as a PFIC (or are treated as a PFIC with respect to a U.S. holder) either in the taxable year of the distribution or the preceding taxable year, but instead will be taxable at rates applicable to ordinary income. Additionally, U.S. holders owning our ADSs or Class B Shares may be subject to certain reporting obligations with respect to our ADSs or Class B Shares for years in which we were a PFIC.

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If we were to be treated as a PFIC, we do not intend to provide the information necessary for U.S. holders of our ADSs or Class B Shares to make “qualified electing fund,” or QEF, elections, which, if available, would result in tax treatment different from the general tax treatment for PFICs described above.

Each U.S. holder should consult its own tax advisors concerning the U.S. federal income tax consequences of holding and disposing of our ADSs or Class B Shares if we were, are or become classified as a PFIC, including the possibility of making a mark-to-market election.

Information Reporting and Backup Withholding.  Dividend payments with respect to ADSs or Class B Shares and proceeds from the sale, exchange or redemption of ADSs or Class B Shares may be subject to information reporting to the IRS and possible U.S. backup withholding. Backup withholding will not apply to you, however, if you furnish a correct taxpayer identification number and make any other required certification or that are otherwise exempt from backup withholding. U.S. holders that are required to establish their exempt status generally must provide such certification on IRS Form W-9. You should consult your tax advisor regarding the application of the U.S. information reporting and backup withholding rules.

Backup withholding is not an additional tax. Amounts withheld as backup withholding can be credited against your U.S. federal income tax liability, and you may obtain a refund of any excess amounts withheld under the backup withholding rules by timely filing the appropriate claim for refund with the IRS and furnishing any required information in a timely manner.

Individual U.S. holders and certain entities may be required to submit to the IRS certain information with respect to his or her beneficial ownership of the ADSs or Class B Shares, if such ADSs or Class B Shares are not held on his or her behalf by a financial institution. This law also imposes penalties if an individual U.S. holder is required to submit such information to the IRS and fails to do so. All U.S. holders are urged to consult their tax advisors regarding the application of information reporting rules to them.

THE DISCUSSION OF U.S. FEDERAL INCOME TAX CONSEQUENCES ABOVE IS NOT TAX ADVICE AND IS NOT INTENDED TO CONSTITUTE A COMPLETE ANALYSIS OF ALL TAX CONSEQUENCES RELATING TO THE OWNERSHIP OR DISPOSITION OF ADSS OR CLASS B SHARES. ALL U.S. HOLDERS ARE URGED TO CONSULT THEIR TAX ADVISORS ABOUT THE APPLICATION OF THE U.S. FEDERAL TAX RULES TO THEIR PARTICULAR CIRCUMSTANCES AS WELL AS THE STATE, LOCAL AND FOREIGN TAX CONSEQUENCES TO THEM OF OWNERSHIP AND DISPOSITION OF ADSS OR CLASS B SHARES.

F. Dividends and Paying Agents

Not applicable.

G. Statement by Experts

Not applicable.

H. Documents on Display

We are subject to the informational requirements of the CNV and BYMA and file reports and other information relating to our business, financial condition and other matters with the CNV and BYMA. You may read such reports, statements and other information, including our publicly filed Financial Statements, at the public reference facilities of the CNV and BYMA maintained in Buenos Aires. We are also required to file annual and special reports and other information with the SEC. You may read and copy any documents filed by us at the SEC’s public reference room at 100 F Street, N.E., Room 1580, Washington, D.C. 20549. Please call the SEC at 1-800-SEC-0330 for further information on the public reference room. Our filings with the SEC will also be available to the public at the offices of the NYSE, 11 Wall Street, New York, New York 10005.

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We have appointed Citibank NA to act as depositary for our ADRs. For so long as our ADRs are deposited with the depositary, we will furnish the depositary with our annual reports and summaries of all notices of general meetings of shareholders and other reports and communications that are made generally available to our shareholders.

The depositary will, as provided in the Deposit Agreement, arrange for the mailing of summaries in English of such reports and communications to all record holders of our ADRs. Any record holder of ADRs may read such reports, notices, or summaries thereof, and communications at the depositary’s office. The depositary’s office is located at 388 Greenwich Street – 6th Floor New York, NY 10013.

Whenever a reference is made in this Annual Report to a contract or other document of ours, please be aware that such reference is not necessarily complete and that you should refer to the exhibits that are a part of the Annual Report for a copy of the contract or other document. You may review a copy of the Annual Report at the SEC’s public reference room in Washington, D.C.

I. Subsidiary Information

Not applicable.

J. Annual Report to Security Holders

Not applicable.

Item 11. Quantitative and Qualitative Disclosures About Market Risk

Our activities are exposed to market risk, including the foreign exchange rate risk, the interest rate risk and the commodity price risk. Financial risks are those derived from financial instruments we are exposed to during or at the closing of each fiscal year. Our risk management policy is defined with the objective of reducing the impact of the loss of purchasing power. Based on this, the Management Committee is in charge of defining policies, procedures, limits and measures to mitigate the impact of such risks.

For further information on our market risks, please see Note 16 to our Audited Financial Statements.

Item 12. Description of Securities Other than Equity Securities

American Depositary Shares

Fees and Charges Payable by a Holder of ADRs

Our ADSs are listed on the NYSE under the symbol “TGS.” Citibank NA is the Depositary of our ADSs pursuant to the Deposit Agreement. Each ADS represents the right to receive five shares.

Under the terms of the Deposit Agreement, as of the date of this Annual Report, an ADS holder may have to pay to the Depositary the fees specified in the table below.

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The charges of the Depositary payable by investors are as follows:

Service	Rate	By Whom Paid
Issuance of ADSs (e.g., an issuance upon a deposit of Shares, upon a change in the ADS(s)-to-Share(s) ratio, or for any other reason), excluding issuances as a result of distributions described in the Deposit Agreement.	Up to US$5.00 per 100 ADSs (or fraction thereof) issued.	Person receiving ADSs.
Cancellation of ADSs (e.g., a cancellation of ADSs for delivery of deposited Shares, upon a change in the ADS(s)-to-Share(s) ratio, or for any other reason).	Up to US$5.00 per 100 ADSs (or fraction thereof) canceled.	Person whose ADSs are being canceled.
Distribution of cash dividends or other cash distributions (e.g., upon a sale of rights and other entitlements).	Up to US$5.00 per 100 ADSs (or fraction thereof) held.	Person to whom the distribution is made.
Distribution of ADSs pursuant to (i) stock dividends or other free stock distributions, or (ii) an exercise of rights to purchase additional ADSs.	Up to US$5.00 per 100 ADSs (or fraction thereof) held.	Person to whom the distribution is made.
Distribution of securities other than ADSs or rights to purchase additional ADSs (e.g., spin-off shares).	Up to US$5.00 per 100 ADSs (or fraction thereof) held.	Person to whom the distribution is made.
ADS Services.	Up to US$5.00 per 100 ADSs (or fraction thereof) held on the applicable record date(s) established by the Depositary.	Person holding ADSs on the applicable record date(s) established by the Depositary.

Disclosure for Fees Incurred in Past Annual Period. From January 1, 2022, to April 20, 2023, we received from the Depositary US$ 1,348 for the expenses incurred by us related to the administration and maintenance of the ADR program and investor relation activities.

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PART II

Item 13. Defaults, Dividend Arrearages and Delinquencies

No events required to be reported have occurred that materially affect tgs.

Item 14. Material Modifications to the Rights of Security Holders and Use of Proceeds

None.

Item 15. Controls and Procedures.

A. Disclosure Controls and Procedures

We carried out an assessment under the supervision and with the participation of our management, including our CEO and CFO, of the effectiveness of the design and operation of our disclosure controls and procedures, as defined under Rules 13a-15(e) and 15d-15(e) under the Exchange Act, as of December 31, 2022. There are inherent limitations to the effectiveness of any system of disclosure controls and procedures, including the possibility of human error and the circumvention or overriding of the controls and procedures. Accordingly, even effective disclosure controls and procedures can only provide reasonable assurance of achieving their control objectives. Based upon this assessment, our CEO and CFO concluded that our disclosure controls and procedures were effective in providing reasonable assurance that information required to be disclosed by us in the reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the applicable rules and forms, and that it is accumulated and communicated to our management, including our CEO and CFO, as appropriate, to allow timely decisions regarding required disclosure.

B. Management’s Annual Report on Internal Control Over Financial Reporting

Our management, including our CEO and CFO, is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. Our internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of Financial Statements for external purposes in accordance with applicable IFRS as issued by the IASB.

Management assessed the effectiveness of our internal control over financial reporting as of December 31, 2022. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (2013). Based on this assessment, management concluded that, as of the end of fiscal year 2022, our internal control over the financial reporting was effective.

C. Attestation Report of the Registered Public Accounting Firm

PwC and EY have jointly audited and reported on the effectiveness of our internal controls over financial reporting as of December 31, 2022, as stated in their reports appearing herein.

D. Changes in Internal Control Over Financial Reporting

There have not been any changes in our internal control over financial reporting during the year ended December 31, 2022 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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Item 16. [Reserved]

Item 16A. Audit Committee Financial Expert

We have one audit committee financial expert serving on our Audit Committee. Our Board of Directors has identified Mr. Carlos Olivieri as an audit committee financial expert. Mr. Olivieri is an independent director within the meaning of Rule 10A-3 under the Exchange Act.

Item 16B. Code of Ethics

We have adopted a code of ethics (the “Code of Ethics”), applicable to all employees, including our principal executive, accounting and financial officers, and all directors. We will provide our Code of Ethics to any person without charge. Our Code of Ethics is available both on our website at https://www.tgs.com.ar/investors/Corporate-governance and is part of our integrity program. The information on our website is not incorporated into this Annual Report.

Any waivers to the Code of Ethics for directors or executive officers requiring disclosure under the NYSE Standards will be disclosed on our website. For more information, see, “Item 16G. Corporate Governance.”

Item 16C. Principal Accountant Fees and Services

Audit and Non-Audit Fees

Fees billed for professional services provided to us by PwC and EY, during the years ended December 31, 2022 and 2021 in each of the following categories are:

	Year ended December 31,
	PwC				EY
	2022		2021		2022		2021
	(in thousands of pesos)
Audit fees		78,874		66,296		78,803		68,890
All other fees		-		-		-		28,496
Total fees		78,874		66,296		78,803		97,386

Audit fees. Audit fees in the above table represent services rendered for the audit of our annual Financial Statements for Form 20-F, the review of our quarterly reports, and services provided by PwC and EY in connection with statutory and regulatory filings or engagements.

All other fees. All other fees in the above table represents on facilitating process improvement rendered by EY.

Audit Committee Pre-Approval Policies and Procedures

Consistent with SEC requirements regarding auditor independence, the Audit Committee pre-approves services prior to commencement of the specified service. Before the accountant is engaged to render audit or non-audit services, the Audit Committee must pre-approve the provision of services by our independent auditors prior to commencement of the specified service. The Audit Committee has delegated to its financial expert the authority to grant pre-approvals to auditors’ services. The decision of the financial expert to pre-approve a service is presented to the full Audit Committee at the next scheduled meetings.

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All audit fees, audit-related fees, tax fees and other fees, if any, are submitted to our Audit Committee for prior approval. The Audit Committee evaluates the scope of the work to be performed by our accountants and the fees for such work prior to their engagement.

Consequently, all services and fees rendered by our independent auditors during the year ended December 31, 2022 were approved by the Audit Committee prior to their engagement to perform such work.

The general annual shareholders´ meeting designates the external auditor.

Item 16D. Exemptions from the Listing Standards for Audit Committees

None.

Item 16E. Purchases of Registered Equity Securities of the Issuer by the Issuer and Affiliated Purchasers

Issuer Purchases of Equity Securities

On May 9, 2018, our Board of Directors approved the First Share Repurchase Program with a maximum amount to invest of Ps. 1,700 million stated at its original value. The chart below shows repurchases conducted under such program through its expiration.

Period	Total number of ADRs purchased		Average price paid per ADRs (U.S.$)		Total Number of Shares Purchased as Part of the Publicly Announced Plan(1)		Maximum Number of Shares that may yet be purchased under the plan
5/11/2018 – 5/31/2018		811,624		17.19		4,058,120		(2	)
6/1/2018 – 6/30/2018		550,175		15.45		2,750,875		(2	)
7/1/2018 – 7/31/2018		359,536		13.69		1,797,680		(2	)
8/1/2018 – 8/31/2018		316,347		13.18		1,581,735		(2	)
9/1/2018 – 9/10/2018		65,400		12.07		327,000		(2	)
		2,103,082				10,515,140

(1) Correspond to the sum of common shares and ADRs purchased. Each ADR represents 5 common shares.

(2) For up to Ps.1,700 million, or any lower amount resulting in such acquisition reaching 10% of our capital stock.

On September 6, 2018, our Board of Directors approved a new share repurchase program with a maximum amount to invest of Ps. 1,800 million stated at its original value. The chart below shows repurchases conducted under such program through its expiration.

Period	Total number of ADRs purchased		Average price paid per ADRs (U.S.$)		Total Number of Shares Purchased as Part of the Publicly Announced Plan(1)		Maximum Number of Shares that may yet be purchased under the plan
10/1/2018 – 10/31/2018		610,974		13.64		3,054,870		(2	)
12/1/2018 – 12/31/2018		6,100		13.43		30,500		(2	)
		617,074				3,085,370

(1) Correspond to the sum of common shares and ADRs purchased. Each ADR represents 5 common shares.

(2) For up to Ps.1,800 million, or any lower amount resulting in such acquisition reaching 10% of our capital stock.

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On March 27, 2019, our Board of Directors approved a new share repurchase program with a maximum amount to invest of Ps.1,500 million stated at its original value. The chart below shows repurchases conducted under such program through its expiration.

Period	Total number of ADRs purchased		Average price paid per ADRs (U.S.$)		Total Number of Shares Purchased as Part of the Publicly Announced Plan(1)		Maximum Number of Shares that may yet be purchased under the plan
04/1/2019 – 04/30/2019		724,275		10.73		3,621,375		(2	)
05/1/2019 – 05/31/2019		636,037		11.08		3,180,185		(2	)
08/1/2019 – 08/26/2019		1,063,706		9.06		5,318,530		(2	)
		2,424,018				12,120,090

(1) Correspond to the sum of common shares and ADRs purchased. Each ADR represents 5 common shares.

(2) For up to Ps.1,500 million, or any lower amount resulting in such acquisition reaching 10% of our capital stock.

On August 26, 2019, our Board of Directors approved a new share repurchase program with a maximum amount to invest of Ps.3,200 million stated at its original value. The chart below shows repurchases conducted under such program through its expiration.

Period	Total number of ADRs purchased		Average price paid per ADRs (U.S.$)		Total Number of Shares Purchased as Part of the Publicly Announced Plan(1)		Maximum Number of Shares that may yet be purchased under the plan
08/28/2019 – 08/31/2019		460,000		7.81		2,300,000		(2	)
09/01/2019 – 09/30/2019		284,785		7.94		1,423,925		(2	)
11/01/2019 – 11/20/2019		644,120		6.27		3,220,600		(2	)
		1,388,905				6,944,525

(1) Correspond to the sum of common shares and ADRs purchased. Each ADR represents 5 common shares.

(2) For up to Ps.3,200 million, or any lower amount resulting in such acquisition reaching 10% of our capital stock.

On November 19, 2019, our Board of Directors approved a new share repurchase program with a maximum amount to invest of Ps.4,000 million stated at its original value. The chart below shows repurchases conducted under such program through its expiration.

Period	Total number of ADRs purchased		Average price paid per ADRs (U.S.$)		Total Number of Shares Purchased as Part of the Publicly Announced Plan(1)		Maximum Number of Shares that may yet be purchased under the plan
11/21/2019 – 11/30/2019		401,000		6.04		2,005,000		(2	)
12/01/2019 – 12/31/2019		932,231		5.97		4,661,155		(2	)
01/01/2020 – 01/31/2020		1,455,121		6.56		7,275,605		(2	)
02/01/2020 – 02/28/2020		555,098		6.21		2,775,490		(2	)
		3,343,450				16,717,250

(1) Correspond to the sum of common shares and ADRs purchased. Each ADR represents 5 common shares.

(2) For up to Ps.4,000 million, or any lower amount resulting in such acquisition reaching 10% of our capital stock.

206

On March 6, 2020, our Board of Directors approved a new share repurchase program with a maximum amount to invest of Ps.2,500 million. The chart below shows repurchases conducted under such program through its expiration.

Period	Total number of ADRs purchased		Average price paid per ADRs (U.S.$)		Total Number of Shares Purchased as Part of the Publicly Announced Plan(1)		Maximum Number of Shares that may yet be purchased under the plan
03/09/2020 – 03/31/2020		1,649,875		4.98		8,249,375		(2	)
04/01/2020 – 04/30/2020		620,668		4.41		3,103,340		(2	)
05/01/2020 – 05/31/2020		386,000		4.32		1,930,000		(2	)
08/01/2020 – 08/31/2020		149,100		4.593		745,500		(3	)
09/01/2020 – 09/30/2020		861,300		4.4191		4,306,500		(3	)
10/01/2020 – 10/31/2020		426,805		4.5231		2,134,025		(3	)

(1) Correspond to the sum of common shares and ADRs purchased. Each ADR represents 5 common shares.

(2) For up to Ps.2,500 million, or any lower amount resulting in such acquisition reaching 10% of our capital stock.

(3) For up to Ps.3,000 million, or any lower amount resulting in such acquisition reaching 10% of our capital stock.

On August 21, 2020 our Board of Directors approved a new share repurchase program with a maximum amount to invest of Ps.3,000 million. The chart below shows repurchases conducted under such program through its expiration.

Period	Average price paid per share (Ps.)		Total Number of Shares Purchased as Part of the Publicly Announced Plan(1)		Maximum Number of Shares that may yet be purchased under the plan
08/01/2020 – 08/31/2020		120.812		117,557		(2	)
09/01/2020 – 09/30/2020		117.146		250,091		(2	)
10/01/2020 – 10/31/2020		147.269		249,897		(2	)

(1) Correspond to the sum of common shares purchased in BYMA.

(2) For up to Ps.3,000 million, or any lower amount resulting in such acquisition reaching 10% of our capital stock.

Item 16F. Change in Registrant’s Certifying Accountant

None.

Item 16G. Corporate Governance

Our corporate governance practices are governed by:

• applicable Argentine law (particularly, the General Companies Act),

• the standards of BYMA,

• Capital Markets Law and Decree No. 1,023/2013,

207

• the standards of the CNV,

• our Bylaws,

• our integrity program and other internal control policies and procedures, and

• certain rules of the NYSE applicable to listed foreign private issuers.

We have securities that are registered with the SEC and listed on the NYSE and, consequently, we are subject to the rules and regulations of the NYSE.

Under the Corporate Governance Standards issued by the NYSE Standards, non-U.S. companies are permitted, in general, to follow their home country corporate governance practices in lieu of the provisions included in such standards. However, non-U.S. companies must comply with sections 303A.06, 303A.11 and 303A.12(b) and (c).

Our Corporate Governance Guidelines are available on our website www.tgs.com.ar.

According to Section 303A.11 of the NYSE Standards, foreign private issuers must disclose any significant ways in which their corporate governance practices differ from those followed by U.S. issuers. Accordingly, the following list reflects such differences:

Directors

According to NYSE Standards, listed companies must have a majority of independent directors. Argentine law does not require a majority of independent directors, but does require at least two independent directors on the Audit Committee. At our Board of Directors meeting held on April 19, 2023, three independent directors, meeting the independence criteria set forth under SEC regulations and NYSE Standards (but under CNV regulations, two qualify as independents) were appointed to the Audit Committee. We also have three alternate directors who qualify as independent.

Meeting of Non-Management Directors

According to NYSE requirements, non-management directors must meet at regularly scheduled executive sessions without management. None of Argentine law, the CNV Rules or our Bylaws requires that any such meetings be held. Under Argentine law, a board of directors must meet at least once every three months.

Nominating/Corporate Governance Committee

U.S. listed companies must have a nominating/corporate governance committee composed entirely of independent directors. Argentine law and regulations do not require us to have a nominating or corporate governance committee.

Compensation Committee

U.S. listed companies must have a compensation committee composed entirely of independent directors. Argentine law and regulations do not require this committee. However, our Audit Committee is required to give an opinion about the reasonableness of directors’ fees and stock option plans (if applicable), as proposed by our Board of Directors, and the compensation paid to members of our Board of Directors is approved by our shareholders at their ordinary annual meeting.

208

Audit Committee

According to SEC regulations and NYSE Standards, listed companies must have an audit committee consisting of a minimum of three independent members. The members of the Audit Committee must be financially literate or must acquire such financial knowledge within a reasonable period and at least one of its members shall have expertise in accounting or financial management. Also, if a member of the Audit Committee is simultaneously a member of the Audit Committee of more than three public companies, and the listed company does not limit the number of Audit Committees on which its members may serve, then, in each case the Board of Directors shall determine whether the simultaneous service would prevent such member from effectively serving on the listed company’s Audit Committee, and shall disclose its decision in the annual proxy statement of the company or in the company’s annual report filed with the SEC.

Argentine law requires an Audit Committee to be comprised of at least three members with a majority of independent members. Pursuant to CNV standards, Audit Committee members are required to have knowledge in business, financial or accounting matters and issues. In addition, CNV standards require the training of Audit Committee members in the practice areas that would permit them to carry out their duties on the Audit Committee. Messrs. Carlos Olivieri, Carlos Alberto Di Brico and Luis Rodolfo Secco are independent directors under SEC regulations and NYSE Standards. Mr. Carlos Alberto Di Brico and Luis Rodolfo Secco are independent directors under CNV regulations.

Mr. Carlos Olivieri qualifies as a “financial expert” within the meaning of Item 16A of Form 20-F. See “Item 16A. Audit Committee Financial Expert.” The Audit Committee’s functions and duties are similar to those required by the NYSE. Furthermore, Argentine law does not limit the number of audit committees on which a member of its Audit Committee may serve.

Code of Conduct

According to Section 303A.10 of the NYSE Standards, listed companies must adopt and disclose a code of business conduct and ethics for directors, officers and employees, and promptly disclose any waivers of the code for directors or executive officers. In October 2005, our Board of Directors approved a “Code of Conduct” with the purpose of introducing SEC rules applicable to foreign registrants. Such code applies to all Board of Directors’ members, senior management, and employees, with no exceptions. Our Code of Conduct is available to the public on our website and as an Exhibit to this Annual Report. Our Code of Conduct is currently an annex of the integrity program.

CEO’s Certification

Each listed company’s CEO must annually certify to the NYSE that he or she is not aware of any violation by the company of the NYSE’s corporate governance listing standards. There is no such requirement under Argentine law.

Item 16H. Mine Safety Disclosure

Not applicable.

Item 16I. Disclosure Regarding Foreign Jurisdictions that Prevent Inspection

Not applicable.

209

Item 16J. Insider Trading Policies

Not applicable.

PART III

Item 17. Financial Statements

The registrant has responded to Item 18 in lieu of responding to this Item.

Item 18. Financial Statements

The following Financial Statements are filed as part of this Form 20-F:

Transportadora de Gas del Sur S.A.

	Page
Reports of independent registered public accounting firms EY, Argentina, PCAOB ID #1449 PwC, Argentina, PCAOB ID #1349	F-1
Consolidated Statements of Comprehensive Income for the years ended December 31, 2022, 2021 and 2020	F-3
Consolidated Statements of Financial Position as of December 31, 2022 and 2021	F-4
Consolidated Statements of Changes in Equity for the years ended December 31, 2022, 2021 and 2020	F-5
Consolidated Statements of Cash Flows for the years ended December 31, 2022, 2021 and 2020	F-6
Notes to Consolidated Financial Statements for the year ended December 31, 2022 and comparative information	F-7

Exhibits No.
1.1	Corporate Charter and Bylaws.(2)
1.2	Bylaws Amendments.(1)
2.4	Indenture dated May 2, 2018, entered into among tgs, Delaware Trust Company as trustee, co-registrar, paying agent and transfer agent, and Banco Santander Rio S.A., as registrar, Argentine paying agent, Argentine transfer agent and representative of the trustee in Argentina, relating to the issuance of tgs’s Class 2, 6.750% senior notes due 2025.(2)
2.5	Officers’ Certificate establishing the terms of tgs’ 6.750% Notes Due 2025.(2)
2.6	Description of Securities Registered under Section 12 of the Exchange Act.(3)
3.1	CIESA Shareholders’ Agreement.(5)
3.2	CIESA’s Fourth Amendment to the Restructuring Agreement.(6)
3.3	CIESA’s Settlement Agreement.(5)

210

4.1	Technical Assistance Service Agreement between tgs and Pampa Energía, dated December 26, 2017.(2)
5.1	Financial lease agreement between Petrobras Argentina and tgs, dated July 25, 2016.(7)
8.1	List of tgs’s Subsidiaries.
11.1	Code of Ethics.(4)
12.1	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
12.2	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
13.1	Certification of Chief Executive Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
13.2	Certification of Chief Financial Officer pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
15.1	Audit Committee Charter.(8)

(1) Amendment incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year ended December 31, 2015 (Commission File No. 1-13396), (ii) amendment previously filed with the Securities and Exchange Commission pursuant to current report on Form 6-K, dated April 12, 2017 (Commission File No. 1-13.396), and (iii) amendment previously filed with the Securities and Exchange Commission pursuant to current report on Form 6-K, dated April 8, 2021 (Commission File No. 1-13.396).

(2) Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year ended December 31, 2018 (Commission File No. 1-13396).

(3) Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year ended December 31, 2019 (Commission File No. 1-13396).

(4) Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year ended December 31, 2005 (Commission File No. 1-13396).

(5) Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year ended December 31, 2012 (Commission File No. 1-13396).

(6) Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year ended December 31, 2010 (Commission File No. 1-13396).

(7) Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year ended December 31, 2017 (Commission File No. 1-13396).

(8) Incorporated by reference to our Annual Report on Form 20-F filed with the Securities and Exchange Commission for the year ended December 31, 2003 (Commission File No. 1-13396).

We agree to furnish to the SEC upon request any instrument with respect to long-term debt that we have not filed as an exhibit pursuant to the exemption provided by instruction 2(b)(i) to Item 19 of Form 20-F.

211

SIGNATURES

The registrant hereby certifies that it meets all of the requirements for filing on Form 20-F and that it has duly caused and authorized the undersigned to sign this Annual Report on its behalf.

TRANSPORTADORA DE GAS DEL SUR S.A.
(Registrant)
By:	/s/ Oscar José Sardi

	Name:	Oscar José Sardi
	Title:	Chief Executive Officer
	/s/ Alejandro M. Basso
	Name:	Alejandro M. Basso
	Title:	Chief Financial Officer and Services Vice President
Dated: April 25, 2023

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRMS

To the Board of Directors and Shareholders of

Transportadora de Gas del Sur S.A.

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated statements of financial position of Transportadora de Gas del Sur S.A. and its subsidiaries (together the “Company”) as of December 31, 2022 and 2021, and the related consolidated statements of comprehensive income, changes in equity and cash flows for each of the three years in the period ended December 31, 2022, and the related notes (collectively referred to as the “consolidated financial statements”).  In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2022 and 2021, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2022, in conformity with International Financial Reporting Standards as issued by the International Accounting Standards Board.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the Company’s internal control over financial reporting as of December 31, 2022, based on criteria established in the Internal Control–Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) and our report dated April 25, 2023 expressed an unqualified opinion thereon.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management.  Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits.  We are public accounting firms registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits of these consolidated financial statements in accordance with the standards of the PCAOB.  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks.  Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements.  Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements.  We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matter

The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that: (i) relates to accounts or disclosures that are material to the consolidated financial statements and (ii) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

Impairment of long-lived assets related to Property, Plant & Equipment of Natural Gas Transportation cash-generating unit

Description of the matter

At December 31, 2022, the Company’s net book value of Property, Plant & Equipment (“PPE”) related to the Natural Gas Transportation cash-generating unit was Argentine Pesos 189,315 million. As discussed in Notes 4 (j) and 5 (a) to the consolidated financial statements, PPE is tested to assess whether an impairment or reversal of a previous impairment is required when significant changes took place during the period, or that will take place in the near future, indicate that the recoverable value of the PPE amounts may be affected. An asset’s recoverable amount is the higher of the fair value less costs to sell that asset, and its value-in-use. The value in use is calculated based on discounted future cash flows. Management’s projected cash flows for the Natural Gas Transportation cash-generating unit considered significant judgements and assumptions relating to: discount rate, estimates of future tariff and the recognition of cost adjustments, and expected macroeconomic variables such interest rates, inflation, foreign exchange rates, among others.

The principal considerations for our determination that performing procedures relating to the impairment of long-lived assets for PPE of Natural Gas Transportation cash-generating unit is a critical audit matter are the significant judgment by management in estimating the value in use of this cash-generating unit, a high degree of auditor judgment, subjectivity and effort in performing procedures and evaluating management’s  significant assumptions related to discount rate, estimates of future tariff and the recognition of cost adjustments and expected macroeconomic variables such as interest rates, inflation and foreign exchange rates. In addition, the audit effort involved professionals with specialized skill and knowledge.

How we addressed the matter in our audit

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These audit procedures included obtaining an understanding, evaluating the design and testing the operating effectiveness of controls over management’s impairment review process, including controls over the review of the significant assumptions. These procedures also included, among others, evaluating the estimation methodology and testing the aforementioned significant assumptions and the completeness, accuracy, and relevance of underlying data used. The significant assumptions were compared with available economic trend data and evaluating the historical accuracy of management’s estimates; sensitivity analyses of the significant assumptions were performed to evaluate the changes in the value in use that would result from changes in the assumptions; the arithmetical accuracy of the discounted cash flows model was evaluated; and the disclosures in the consolidated financial statements were assessed. Professionals with specialized skill and knowledge were involved to assist in the evaluation of the methodology and the significant assumptions used in the future cash flows estimated by management.

/s/ Price Waterhouse & Co. S.R.L.	/s/ Pistrelli, Henry Martin y Asociados S.R.L.
	PISTRELLI, HENRY MARTIN Y ASOCIADOS S.R.L
/s/Fernando Alberto Rodriguez	Member of Ernst & Young Global Limited

Price Waterhouse & Co. S.R.L (“PwC”) has served as the Company’s sole auditor since 2012. PwC and Pistrelli, Henry Martin y Asociados S.R.L have served as the Company’s joint auditors since 2017.

Buenos Aires, Argentina

April 25, 2023

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRMS

To the Board of Directors and Shareholders of

Transportadora de Gas del Sur S.A.

Opinion on the Internal Control over Financial Reporting

We have audited Transportadora de Gas del Sur S.A. and its subsidiaries (together the “Company”) internal control over financial reporting as of December 31, 2022, based on criteria established in Internal Control  Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (“the COSO”). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2022, based on the COSO criteria.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States of America) (“PCAOB”), the consolidated statements of financial position of the Company as of December 31, 2022 and 2021, and the related consolidated statements of comprehensive income, changes in equity and cash flows for each of the three years in the period ended December 31, 2022, and the related notes (collectively referred to as the “consolidated financial statements”), and our report dated April 25, 2023 expressed an unqualified opinion thereon.

Basis for Opinion

The Company's management is responsible for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting included in the Management’s Annual Report on Internal Control over Financial Reporting appearing under Item 15.  Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit.  We are public accounting firms registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB.  Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects.

Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ Price Waterhouse & Co. S.R.L.	/s/ Pistrelli, Henry Martin y Asociados S.R.L.
	PISTRELLI, HENRY MARTIN Y ASOCIADOS S.R.L
/s/Fernando Alberto Rodriguez	Member of Ernst & Young Global Limited

Buenos Aires, Argentina

April 25, 2023

F-2

TRANSPORTADORA DE GAS DEL SUR S.A.

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

FOR THE YEARS ENDED DECEMBER 31, 2022, 2021 AND 2020

 (Stated in thousands of pesos as described in Note 3 and 4.d. except for share and per share information)

	Notes		2022			2021			2020
Revenues		8.h.		164,524,789			173,319,821			164,275,443
Net cost of sales		8.i.		(96,041,564	)		(92,843,404	)		(81,049,791	)
Gross profit				68,483,225			80,476,417			83,225,652
Administrative expenses		8.j.		(5,754,433	)		(4,996,067	)		(4,947,813	)
Selling expenses		8.j.		(10,203,597	)		(9,339,564	)		(8,725,879	)
Other operating results		8.l.		(76,498	)		250,925			293,522
Impairment of PPE		5.a.		-			-			(9,156,072	)
Operating profit				52,448,697			66,391,711			60,689,410
Net financial results
Financial income		8.k.		29,776,707			13,386,552			16,216,663
Financial expenses		8.k.		(58,904,450	)		(32,942,739	)		(53,495,791	)
Other financial results		8.k.		22,199,580			395,150			(19,919,477	)
Gain on net monetary position		8.k.		3,768,283			18,311,140			19,058,813
Total net financial results				(3,159,880	)		(849,897	)		(38,139,792	)
Share of profit from associates		11		90,138			41,347			62,657
Net income before income tax				49,378,955			65,583,161			22,612,275
Income tax expense		14		(17,061,153	)		(24,810,849	)		(12,950,061	)
Total comprehensive income for the year				32,317,802			40,772,312			9,662,214
Total comprehensive income attributable to:
Owners of the Company				32,317,790			40,772,306			9,662,187
Non-controlling interests				12			6			27
Total comprehensive income for the year				32,317,802			40,772,312			9,662,214
Total comprehensive income per share attributable to owners of the Company:
Weighted average of outstanding ordinary shares *				752,761,058			752,761,058			762,371,755
Basic and diluted earnings per share				42.93			54.16			12.68

*The weighted average of the number of shares considers the effect of the weighted average of the changes originated in the transactions with treasury shares made during the year.

The accompanying notes are an integral part of these consolidated financial statements.

F-3

TRANSPORTADORA DE GAS DEL SUR S.A.

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION

AS OF DECEMBER 31, 2022 AND 2021

(Stated in thousands of pesos as described in Note 3 and 4.d.)

	Notes		2022			2021
ASSETS
Non-current assets
Property, plant and equipment		12		294,479,596			292,534,643
Investments in associates		9		154,502			64,371
Financial assets measured at amortised cost		8.m.		40,162,283			43,720,399
Deferred income tax asset		14		27,410			46,277
Other receivables		8.a.		14,899			17,249
Total non-current assets				334,838,690			336,382,939
Current assets
Other receivables		8.a.		16,176,638			11,642,263
Inventories				1,833,545			2,278,309
Trade receivables		8.b.		16,939,295			20,693,854
Contract assets				24,043			46,834
Financial assets measured at amortised cost		8.m.		1,438			3,721
Financial assets at fair value through profit or loss		8.n.		39,289,630			25,844,992
Cash and cash equivalents		8.c.		2,988,946			8,627,004
Total current assets				77,253,535			69,136,977
Total Assets				412,092,225			405,519,916
EQUITY
Common stock				108,907,931			108,907,931
Treasury shares				6,037,989			6,037,989
Cost of acquisition of treasury shares				(10,924,539	)		(10,924,539	)
Additional paid-up capital				(3,169,112	)		(3,169,112	)
Legal reserve				12,779,853			10,741,238
Reserve for capital expenditures, acquisition of treasury shares and/or dividends				121,274,267			82,540,576
Accumulated retained earnings				32,317,790			40,772,306
Non-controlling interests				110			98
Total equity				267,224,289			234,906,487
LIABILITES
Non-current liabilities
Deferred tax liabilities		14		21,248,327			20,063,665
Taxes payables		8.f.		14,285			-
Contract liabilities		8.d.		11,717,412			10,963,157
Loans		13		90,694,136			100,121,274
Total non-current liabilities				123,674,160			131,148,096
Current liabilities
Provisions		15		1,834,094			2,524,233
Contract liabilities		8.d.		1,045,454			978,575
Other payables		8.e.		286,555			619,970
Taxes payables		8.f.		944,696			1,297,426
Income tax payable				8,283			17,067,810
Payroll and social security taxes payable		8.o.		2,629,829			2,774,569
Loans		13		3,919,929			2,299,738
Derivative financial instruments		16.1.1		-			82,329
Trade payables		8.g.		10,524,936			11,820,683
Total current liabilities				21,193,776			39,465,333
Total liabilities				144,867,936			170,613,429
Total equity and liabilities				412,092,225			405,519,916

The accompanying notes are an integral part of these consolidated financial statements.

F-4

TRANSPORTADORA DE GAS DEL SUR S.A.

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

FOR THE YEARS ENDED DECEMBER 31, 2022, 2021 AND 2020

(Stated in thousands of pesos as described in Note 3 and 4.d.)

	Shareholders Contributions																			Retained Earnings
	Outstanding shares						Treasury shares															Reserve for
				Inflation					Inflation		Acquisition cost											capital expenditures,
	Common			adjustment			Common		adjustment		of treasury			Additional paid-up								acquisition of											Non-Controlling
	stock			to common			stock (1)		to common		shares (1)			capital (2)						Legal		treasury shares			Accumulated			Subtotal		Total			interests			Total
				stock					stock (1)								Subtotal			reserve		and/or dividends			retained earnings
Balances at December 31, 2019		784,608			112,695,920			9,887		1,455,505		(2,925,145	)		(3,169,112	)		108,851,663			7,695,275		21,419,795			54,504,557			83,619,627		192,471,290			112			192,471,402
Treasury shares purchase		(31,847	)		(4,540,750	)		31,847		4,540,750		(7,999,394	)		-			(7,999,394	)		-		-			-			-		(7,999,394	)		-			(7,999,394	)
Resolutions of the Ordinary and Extraordinay Shareholders
Meeting held on April 21, 2020
Legal Reserve		-			-			-		-		-			-			-			2,562,853		-			(2,562,853	)		-		-			-			-
Dividends payment		-			-			-		-		-			-			-			-		-			-			-		-			-			-
Derecognition of reserves		-			-			-		-		-			-			-			-		(21,419,795	)		21,419,795			-		-			-			-
Reserve for capital expenditures, acquisition of treasury shares and/or dividends		-			-			-		-		-			-			-			-		73,361,499			(73,361,499	)		-		-			-			-
Non-controlling interests dividends payment		-			-			-		-		-			-			-			-		-			-			-		-			(47	)		(47	)
Comprehensive income for the year		-			-			-		-		-			-			-			-		-			9,662,187			9,662,187		9,662,187			27			9,662,214
Balances at December 31, 2020		752,761			108,155,170			41,734		5,996,255		(10,924,539	)		(3,169,112	)		100,852,269			10,258,128		73,361,499			9,662,187			93,281,814		194,134,083			92			194,134,175
Resolutions of the Ordinary and Extraordinay Shareholders
Meeting held on April 20, 2021
Legal Reserve		-			-			-		-		-			-			-			483,110		-			(483,110.00	)		-		-			-			-
Derecognition of reserves		-			-			-		-		-			-			-			-		(73,361,499	)		73,361,499.00			-		-			-			-
Reserve for capital expenditures, acquisition of treasury shares and/or dividends		-			-			-		-		-			-			-			-		82,540,576			(82,540,576.00	)		-		-			-			-
Comprehensive income for the year		-			-			-		-		-			-			-			-		-			40,772,306			40,772,306		40,772,306			6			40,772,312
Balances at December 31, 2021		752,761			108,155,170			41,734		5,996,255		(10,924,539	)		(3,169,112	)		100,852,269			10,741,238		82,540,576			40,772,306			134,054,120		234,906,389			98			234,906,487
Resolutions of the Ordinary Shareholders
Meeting held on April 5, 2022
Legal Reserve		-			-			-		-		-			-			-			2,038,615		-			(2,038,615	)		-		-			-			-
Derecognition of reserves		-			-			-		-		-			-			-			-		(82,540,576	)		82,540,576			-		-			-			-
Reserve for capital expenditures, acquisition of treasury shares and/or dividends		-			-			-		-		-			-			-			-		121,274,267			(121,274,267	)		-		-			-			-
Comprehensive income for the year		-			-			-		-		-			-			-			-		-			32,317,790			32,317,790		32,317,790			12			32,317,802
Balances at December 31, 2022		752,761			108,155,170			41,734		5,996,255		(10,924,539	)		(3,169,112	)		100,852,269			12,779,853		121,274,267			32,317,790			166,371,910		267,224,179			110			267,224,289

⁽¹⁾ As of December 31, 2022, 2021 and 2020 corresponds to 41,734,225 shares of par value Ps. 1 each, equivalent to 5.25% of the share capital. The acquisition cost of these shares amounted to Ps. 10,924,539. See Note 19.b) to the consolidated financial statements.

(2) See Note 19.b).

The accompanying notes are an integral part of these consolidated financial statements.

F-5

TRANSPORTADORA DE GAS DEL SUR S.A.

CONSOLIDATED STATEMENTS OF CASH FLOWS

FOR THE YEARS ENDED DECEMBER 31, 2022, 2021 AND 2020

(Stated in thousands of pesos as described in Note 3 and 4.d.)

	2022			2021			2020
CASH FLOWS PROVIDED BY OPERATING ACTIVITIES
Total comprehensive income for the year		32,317,802			40,772,312			9,662,214
Reconciliation of total comprehensive income to cash flows provided by operating activities:
Depreciation of property, plant and equipment		19,572,669			18,721,149			18,115,502
Derivative financial instrument results		127,585			157,227			(1,321,859	)
Disposal of property, plant and equipment		96,242			125,836			102,586
Share of gain from associates		(90,138	)		(41,347	)		(62,657	)
Increase in provisions		775,831			1,026,961			955,990
Interest expense accrual, net		6,537,595			8,392,366			9,455,473
Interest (loss) / income on other financial assets other than cash and cash equivalents		(21,176,519	)		3,559,483			22,890,324
Income tax		17,061,153			24,810,849			12,950,061
Impairment of PPE		-			-			9,156,072
Notes repurchase result		1,030,169			806,841			(1,174,202	)
Allowance for doubtful accounts		-			(129,715	)		279,520
Foreign exchange loss, net		28,102,079			12,922,876			33,974,755
Loss on net monetary position		(9,107,531	)		(21,839,164	)		(20,638,648	)
Changes in assets and liabilities:
Trade receivables		(7,812,886	)		(10,879,283	)		(893,154	)
Other receivables		(6,510,381	)		(8,226,280	)		(1,627,647	)
Inventories		(663,941	)		(1,165,062	)		(775,818	)
Trade payables		4,439,683			5,261,196			422,732
Contract assets		-			186,898			168,414
Payroll and social security taxes		1,157,960			538,358			1,468,758
Taxes payables		310,109			644,834			18,523
Other payables		(32,423	)		31,745			42,089
Provisions		(20,248	)		(9,751	)		(23,737	)
Interest paid		(5,725,137	)		(7,304,538	)		(8,077,195	)
Income tax paid		(25,687,559	)		(8,360,256	)		(3,430,707	)
Contract liabilities		821,246			(906,573	)		254,990
Derivative financial instruments payment		(109,299	)		(73,392	)		1,945,363
Cash flows provided by operating activities		35,414,061			59,023,570			83,837,742
CASH FLOWS USED IN INVESTING ACTIVITIES
Additions to property, plant and equipment		(25,307,541	)		(18,794,792	)		(22,844,489	)
Dividends received		-			354,492			-
Financial assets not considered cash equivalents		(14,908,086	)		(40,550,286	)		(65,621,123	)
Cash flows used in investing activities		(40,215,627	)		(58,990,586	)		(88,465,612	)
CASH FLOWS PROVIDED BY / (USED IN) FINANCING ACTIVITIES
Payment of loans		(86,187	)		-			(3,981,411	)
Proceeds from loans		6,164,853			-			-
Cost of acquisition of treasury shares		-			-			(7,999,394	)
Dividends paid		-			-			(47	)
Cost of repurchase of notes		(2,452,516	)		(1,869,224	)		(2,939,684	)
Cash flows provided by / (used in) financing activities		3,626,150			(1,869,224	)		(14,920,536	)
NET DECREASE IN CASH AND CASH EQUIVALENTS		(1,175,416	)		(1,836,240	)		(19,548,406	)

Cash and cash equivalents at the beginning of the year	8,627,004		13,682,131		39,088,735
Foreign exchange gain on Cash and cash equivalents	292,549		629,531		2,236,421
Monetary results effect on Cash and cash equivalents	(4,755,191	)	(3,848,418	)	(8,094,619	)
Cash and cash equivalents at the end of the year	2,988,946		8,627,004		13,682,131

The accompanying notes are an integral part of these consolidated financial statements.

For further information, see Note 6.

F-6

TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

1. BUSINESS DESCRIPTION

Business Overview

Transportadora de Gas del Sur S.A. (“tgs” or the “Company”) is one of the companies created as a result of the privatization of Gas del Estado S.E. (“GdE”). tgs commenced operations on December 28, 1992 and it is mainly engaged in the Transportation of Natural Gas, and Production and Commercialization of natural gas Liquids (“Liquids”). tgs’s pipeline system connects major natural gas fields in southern and western Argentina with natural gas distributors and industries in those areas and in the greater Buenos Aires area. The natural gas transportation license to operate this system was exclusively granted to tgs for a period of thirty-five years (“the License”). tgs is entitled to a one-time extension of ten years provided that it has essentially met the obligations imposed by the License and by the Ente Nacional Regulador del Gas (National Gas Regulatory Body or “ENARGAS”). The General Cerri Gas Processing Complex (the “Cerri Complex”), where tgs processes natural gas by extracting liquids, was transferred from GdE along with the gas transmission assets. tgs also provides midstream services, which mainly consist of gas treatment, removal of impurities from the natural gas stream, gas compression, gas transportation in fields, wellhead gas gathering and pipeline construction, operation and maintenance services. Also, telecommunications services are provided through the subsidiary Telcosur S.A. (“Telcosur”). These services consist of data transmission services through a network of digital terrestrial radio relay.

Subsequently, the corporate purpose of the Company was modified to incorporate the development of complementary activities, incidental, linked and / or derived from natural gas transportation, such as the generation and commercialization of electric power and the provision of other services for the hydrocarbon sector in general.

Major Shareholders

tgs’s controlling shareholder is Compañía de Inversiones de Energía S.A. (“CIESA”), which holds 51% of the common stock. CIESA is under joint control and in equal parts of: (i) Pampa Energía S.A. (“Pampa Energía”) with 50%; (ii) Grupo Inversor Petroquímica S.L. (member of the GIP Group, led by the Sielecki family) and PCT L.L.C. with the remaining 50%. Local and foreign investors hold the remaining ownership of tgs’s common stock.

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Table of Contents

TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The following table shows the organizational structure, shareholders and related parties of tgs as of December 31, 2022:

44%, 24%, 8%, 12%, 5%, 51%, 49%, 51%, 49%, 99.98%, 0.02%, 80%, 15%, 5%, 100%, 49%, 25.5%, 20.4%, 5.1%

Economic context

The Company operates in a complex economic context whose main variables have recently had strong volatility as a result of health events generated by the COVID19 pandemic, political and economic events both domestically and internationally.

During the first quarter of 2022, Argentina and the IMF reached an agreement where fiscal and monetary goals were established and a refinancing of maturities was obtained. However, the inflationary inertia continues, and as of December 31, 2022, year-on-year inflation reached 94.8%.

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Table of Contents

TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

In addition, the conflict between Russia and Ukraine has been a major factor of global destabilization that led to a significant increase in the price of commodities, including natural gas. In this context, on April 7, 2022, the Argentine Government announced an agreement for the supply of natural gas from Bolivia during the winter period. The increase in natural gas prices could negatively affect Argentina’s current fiscal imbalance. Also, the availability and price of natural gas are key factors for the normal development of the Cerri Complex’s Liquids production activities.

The main macroeconomic issues and the measures adopted by the Government are described below:

Economic activity, poverty and unemployment

In recent years, the Argentine economy suffered a significant impact from the crisis generated by COVID-19 to the difficult moment that the international economy is experiencing due to high inflation and the conflict between Russia and Ukraine.

In this sense, after the abrupt economic slowdown produced in 2020 as a result of the sanitary measures imposed, the economy has begun a path of recovery in 2021, reaching an increase of 10.4% in the Monthly Estimator of Economic Activity (“EMAE”). This trend was reduced during 2022, showing that indicator a positive variation, as of November of that year, of 2.6% year-on-year. Recent estimates predict that given the volatile Argentine and international situation, economic growth would slow down during 2023.

Additionally, the unemployment rate presented a rate of 7.1% for the third quarter of 2022, according to the latest information provided by INDEC.

Likewise, the pandemic has had a profound initial impact on the lowest-income sectors. The latest official statistical data available from INDEC corresponds to the first semester of 2022, and indicates that in that period poverty reached 36.5%.

Fiscal imbalance

The primary fiscal deficit continued to be high, amounting in 2022 to 2.4% of the Gross Domestic Product (“GDP”). For its part, the financial deficit amounted to 4.2% of GDP. The reduction compared to 2021 was mainly due to the reorganization of the fiscal accounts carried out in order to meet the goals agreed with the IMF in the Extended Facilities Program.

Tariff policy

Reducing the fiscal deficit is one of the central issues within the framework of the principle of agreement with the IMF, and a large part of the deficit is explained by the growth of subsidies that cover the delay with tariffs. Public services tariffs have been virtually (in some cases completely and in others partially) frozen for almost 24 months.

During 2022, public service companies only received temporary rate increases since the comprehensive rate review (“RTI”) renegotiation process has not been completed. In fact, towards the end of 2022, the Government extended its completion period until the end of 2023. For more information, see “Note 17 – Regulatory framework.”

Likewise, in order to encourage production, to reduce the impact on certain types of natural gas consumers and to reduce the subsidies paid to natural gas producers, as from November 2020, the Plan for the Promotion of Argentine Natural Gas Production - Supply and Demand Scheme 2020-2024 was established through Decree No. 892/2020 (the “Gas.Ar Plan”).

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Monetary imbalance and inflation

The country faces certain monetary imbalances aggravated by the high level of monetary issue as a result of the assistance measures adopted by the Government, thus pressing the international reserves of the Banco Central de la República Argentina (“BCRA”). The fall in the BCRA’s international reserves, accompanied by an increase in its monetary liabilities, has led to a tightening of the foreign exchange regulations that imposed restrictions on the accumulation and consumption of foreign currency and payments abroad, which in turn generated a significant gap between the official exchange rate and that of freer trading venues. For further information, see “Note 16 - Financial Risk Management”.

In order to deal with this situation, the Government has adopted several measures, among which we can mention: maximum price plans for certain food products, limitations to increases in utility tariffs and a limited exchange rate devaluation policy.

According to the latest Survey of Market Expectations (“REM”) carried out by the BCRA corresponding to December 2023, the median resulting from the estimates made by the 37 participants of the REM, showed an expected inflation of 110% for 2023.

Public debt

In 2022, an extremely important milestone was achieved, which was the agreement reached with the International Monetary Fund (“IMF”) for a new Extended Facilities Program. With a duration of 30 months, disbursements are made over 10 years, four and a half years of grace, this program allows the country to postpone its maturities with the agency and strengthen its reserves in the short term. Among the commitments assumed is gradual fiscal consolidation -reaching equilibrium in 2025- together with the reduction of monetary financing of the deficit and the accumulation of reserves to gain some freedom in monetary policy.

Exchange market

The low level of reserves in the BCRA has led the National Government to maintain a very restrictive exchange control for the purchase of foreign currency in the single free market for foreign exchange (“MULC”), in which the price of the US dollar at 31 December 2022 was $176.96 (buyer) and $177.16 (seller), representing an increase of approximately 72%, well below inflation as measured by the CPI. However, as of December 31, 2022, the gap with respect to the alternative quotations of the US dollar obtained in the market was close to 100%.

Since the primary elections that took place in September 2021, the BCRA had to tighten the exchange rate clamp to try to stop the leak of foreign currency, establishing, among other measures, greater restrictions on access to the MULC for imports. For further information, see “Note 16.1.1. – Risk associated with exchange rate”.

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Table of Contents

TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The current economic context and in particular, the exchange market generates expectations that the local currency will continue to devaluate, being a relevant aspect the speed with which this issue may develop in the next months, as well as other restrictions and/or developments in the exchange market with effects on different aspects of the economic activity, such as foreign trade and others.

The Company’s management permanently monitors the evolution of the situations affecting its business, in order to determine the possible actions to be taken and identify the eventual impacts on its financial position and the results of its operations. The Company’s financial statements should be read considering these circumstances.

2. CONSOLIDATED FINANCIAL STATEMENTS

tgs presents its consolidated financial statements including Telcosur S.A. (“Telcosur”), CTG Energía S.A. (“CTG”) and TGSLatam Energía S.A. (“TGSLatam”), its consolidated subsidiaries, which are jointly referred to as “tgs” or “the Company”.

These consolidated financial statements were approved and authorized for issuance by the Company’s Board of Directors on April 25, 2023.

3. BASIS OF PRESENTATION

These consolidated financial statements have been prepared in accordance with International Financial Reporting Standards issued by the International Accounting Standards Board (“IASB”) and the International Financial Interpretations Committee (“IFRIC”), jointly the “IFRS”).

The CNV, in Title IV, Chapter III, Article 1 of the Rules has provided that listed companies must submit their consolidated financial statements by applying Technical Resolution No. 26 of the Argentine Federation of Professional Councils of Economic Sciences (“FACPCE”), which adopts the International Financial Reporting Standards (“IFRS”) issued by the IASB, its amendments and circulars for the adoption of IFRS that the FACPCE dictates in accordance with the provisions of that Technical Resolution.

The preparation of the consolidated financial statements in conformity with IFRS requires management to make accounting estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements, as well as the reported amounts of revenues and expenses during the reporting fiscal year. Estimates are used when accounting for the allowance for doubtful accounts, income taxes, provisions for legal claims and others, depreciations and recoverable value of assets. Actual results could be significantly different from such estimates.

The presentation in the statement of financial position distinguishes between current and non-current assets and liabilities. The assets and liabilities are those expected to be realized or settled within twelve months after the end of the reporting period under review, and those held for sale. The fiscal year begins on January 1 and ends on December 31 of each year. The economic and financial results are presented on a fiscal year basis.

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Table of Contents

TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The consolidated financial statements have been stated in terms of the measuring unit current as of December 31, 2022 in accordance with IAS 29 “Financial reporting in hyperinflationary economies” and are stated in thousands of Argentine pesos (“Ps.” Or “pesos”) which is the functional currency of the Company, unless otherwise stated. For further information, see Note 4.c).

4. SIGNIFICANT ACCOUNTING POLICIES

4.a) New accounting standards

4.a 1) New standards and interpretations issued by the IASB effective for the years beginning on or after January 1, 2022 adopted by the Company

The new accounting standards, amendments and interpretations issued by the IASB that became effective as of January 1, 2022 and that have not had an impact on the Company’s consolidated financial statements are the following:

IAS 16 - Property, plant and equipment (“PPE”) – Proceeds before intended use

In May 2020, the IASB issued an amendment to IAS 16 that prohibits entities from deducting from the cost of an item of PPE the revenue from the sale of items produced while bringing that asset into use. Instead, an entity shall recognize the revenue from the sale of such items, as well as the costs of production of those items, in profit or loss.

This amendment became effective for annual periods that began on or after January 1, 2022 and should be applied retrospectively to items of PPE that are available for use from the beginning of the earliest period presented when the company first applies the amendment.

The amendments did not have a significant impact on the Company’s consolidated financial statements.

IAS 37: Onerous Contracts: Cost of Fulfilling a Contract

In May 2020, the IASB issued amendments to IAS 37 to specify which costs an entit should include when assessing whether a contract is onerous.

These amendments clarify the meaning of “costs to fulfill a contract”. Costs that relate directly to a contract for the supply of goods or services include both incremental costs and an allocation of costs directly related to contract activities.

These amendments became effective for annual reporting periods that began on or after January 1, 2022.

The amendments did not have a significant impact on the Company´s consolidated financial statements.

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Table of Contents

TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

4.a.2) New IFRS issued that are not yet effective for the year beginning January 1, 2022.

The IFRS that potentially have an impact on the Company, which are not mandatory and have not been adopted early in the year beginning January 1, 2022, are listed below:

Classification of debt as current and non-current (amendment to IAS 1)

On January 23, 2020, the IASB issued the classification of debt as current and non-current, which amends IAS 1 Presentation of Financial Statements. These amendments affect the requirements of IAS 1 for the presentation of debt.

Specifically, it clarifies the criteria for classifying debt as non-current. The date of application of the amendment was set for fiscal years beginning on or after January 1, 2023, with retroactive application. The Company is evaluating the impact of these amendments for the presentation of debt.

IAS 12: “Income tax”

IAS 12 - Income Tax specifies how an entity accounts for income tax, including deferred tax, which represents tax to be paid or recovered in future periods.

The amendments clarify that the exemption defined in the standard to recognize deferred taxes when assets or liabilities are recognized for the first time is not applicable in the case of leases and provisions for decommissioning.

The amendments are effective for annual reporting periods beginning on or after January 1, 2023 and early application is permitted.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

IAS 8: “Accounting Policies, Changes in Accounting Estimates and Errors”

In February 2021, the IASB issued amendments to IAS 8, introducing a definition of “accounting estimates”. The amendments clarify the distinction between changes in accounting estimates and changes in accounting policies and the correction of errors. They also clarify how entities use measurement techniques and inputs to develop accounting estimates.

The modifications are effective for annual reporting periods that began on or after January 1, 2023.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

IAS 1: Disclosure of accounting policies – Practice Statement 2

In February 2021, the IASB issued amendments to IAS 1 and IFRS Practice Statement 2, Making Materiality, providing guidance and examples to help entities apply disclosure materiality judgments on accounting policies. The purpose of the amendments is to help entities provide information about accounting policies that is more useful, by replacing the requirement that entities disclose their “significant” accounting policies with “material” accounting policies and by adding guidance on how Entities apply the concept of materiality when making decisions about disclosures regarding accounting policies.

The modifications are effective for annual reporting periods that began on or after January 1, 2023.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

4.b) Consolidation

4.b.1) Subsidiaries

Subsidiaries are all entities over which the Company has control. The Company controls an entity when the Company is exposed to, or has rights to, variable returns from its involvement and has the ability to affect those returns through its power over the entity. Subsidiaries are fully consolidated from the date on which control is transferred to the group. They are deconsolidated from the date that control ceases. For this purpose and unless there are specific requirements, it is generally considered that tgs has control, when it has a participation equal to or greater than 50% of the available voting rights.

The accounting policies of the subsidiaries are consistent with the accounting policies adopted by the Company.

Inter-company transactions, balances and profit or loss from transactions between group companies are eliminated. Unrealized profit or loss are also eliminated.

Detailed data reflecting subsidiary control as of December 31, 2022 and 2021 is as follows:

		% of shareholding and voting
Company	Incorporation country	Direct			Indirect			Closing date	Main activity
Telcosur	Argentina		99.98	%		-		December 31	Telecommunication Services
CTG	Argentina		100	%		-		December 31	Electricity related services
TGSLatam	Bolivia		80	%		100	%	December 31	Hydrocarbons and Electrical power related services

For consolidation purposes for the year ended December 31, 2022, the financial statements of Telcosur and TGSLatam have been used at those dates. The subsidiary CTG does not record operations or significant assets and liabilities as of December 31, 2022 and 2021.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

4.b.2) Associates

Associates are entities over which the group has significant influence but not control, generally accompanying a shareholding of between 20% and 50% of the voting rights. Investments in associates are accounted for using the equity method of accounting. Under the equity method, the investment is initially recognized at cost, and the carrying amount is increased or decreased to recognize the investor’s share of the profit or loss of the investee after the date of acquisition.

The Company accounted for the investments in its associates, under the equity method on the basis on the financial statements as of September 30, 2022 of Gas Link S.A. (“Link”), Transporte y Servicios de Gas en Uruguay SA (“TGU”) and Emprendimientos de Gas del Sur S.A. (“EGS”), under liquidation. Accounting policies of associates have been changed where necessary to ensure consistency with the policies adopted by the Company. The Company’s management is not aware of any significant subsequent events which affected the financial statements as of September 30, 2022 of Link, TGU and EGS (in liquidation) from this date to December 31, 2022.

Unrealized gains and losses resulting from transactions between tgs and the associate or joint venture are eliminated to the extent of the interest in the associate or joint venture.

In the table below, associates are disclosed, together with the percentage of shareholding and voting as of December 31, 2022 and 2021:

Company	% of shareholding and voting	Country	Main activity	Closing date
TGU	49.00%	Uruguay	Pipeline maintenance	December 31
EGS (“in liquidation”)	49.00%	Argentina	Pipeline exploitation and construction	December 31
Link	49.00%	Argentina	Pipeline exploitation and construction	December 31

4.b.3) Joint arrangement

As indicated in “Note 23 – Associates and Joint Arrangement”, on August 7, 2017, the Company proceeded to create a UT (similar to a joint operation) with SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A. (“SACDE”) (“UT”). This operation is evaluated as a joint agreement under the provisions included in “IFRS 11 - Joint Arrangements” since the parties have joint control of the operation, meaning that the decisions of the relevant activities are taken under the unanimous consent of the parties.

The Company has defined that the UT constitutes a joint operation given that it grants its participants a percentage of the rights over the assets and liabilities arising from each contract. Accordingly, the Company recognizes its share in the jointly operated assets, liabilities, revenues, costs and expenses.

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Table of Contents

TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Accounting policies applicable to the UT have been modified and adapted, if applicable, to ensure consistency with the policies adopted by the Company. For further information regarding the UT, see Note 23.

4.c) 
Foreign currency translation

4.c.1) Functional and presentation currency

The consolidated financial statements are presented in thousands of Argentine Pesos, which is the Company’s functional currency. Each subsidiary or associate determines its own functional currency based on the currency of the primary economic environment in which these entities operate.

4.c.2) Transactions and balances

Foreign currency transactions are translated into the functional currency using the exchange rate prevailing at the dates of the transactions or valuation where items are remeasured. Foreign exchange gains and losses resulting from the settlement of such transactions and from the translation at year-end exchange rates of monetary assets and liabilities denominated in foreign currencies are recognized in the profit or loss for the year.

Foreign exchange gains and losses are presented in the statement of comprehensive income within financial income and financial expenses, as appropriate.

4.c.3) Associates

The functional currency of the associate company TGU, which is located abroad, is the US dollar, because it is the currency in which it substantially generates its income and incurs its expenses. Assets and liabilities were converted into Argentine pesos using the exchange rate prevailing at the end of each year, their common stock and retained earnings at their historical exchange rates and results at average exchange rates.

4.d) Restatement to constant currency - Comparative Information

4.d.1) Regulatory framework

The consolidated financial statements as of December 31, 2022, including comparative figures, have been restated to take into account changes in the general purchasing power of the Company’s functional currency (the Argentine peso) in accordance with IAS 29 “Financial Reporting in hyperinflationary economies” (“IAS 29”) and CNV General Resolution No. 777/2018. As a result, the financial statements are stated in terms of the current unit of measurement at the 2022 balance sheet date.

IAS 29 requires that the financial statements of an entity that reports in the currency of a hyperinflationary economy, regardless of whether they are based on the historical cost method or the current cost method, are expressed in terms of the current unit of measurement at the closing date of the reporting period. In order to conclude on the existence of a hyperinflationary economy, the standard details a series of factors to be considered, among which is a cumulative inflation rate over three years that approaches or exceeds 100%.

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Table of Contents

TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The accumulated inflation in three years is over 100%. Likewise, both the National Government projections and other available projections indicate that this trend will not be reversed in the short term.

To evaluate the aforementioned quantitative condition, and also to restate the financial statements, the CNV has established that the series of indexes to be used for the application of IAS 29 is determined by the FACPCE. This series of indexes combines the National Consumer Price Index (“CPI”) as of January 2017 (base month: December 2016) with the Domestic Wholesale Price Index (“IPIM”), both published by the Institute National Statistics and Census (“INDEC”) until that date. For the months of November and December 2015, for which there is no information from the INDEC on the evolution of the IPIM, the variation in the CPI of the Autonomous City of Buenos Aires was applied.

Considering the aforementioned index, inflation was 94.79%, 50.94% and 36.14% in the years ended December 31, 2022, 2021 and 2020 respectively.

4.d.2) Restatement mechanism

The financial statements must be adjusted to consider changes in the general purchasing power of the currency, so that they are expressed in the current unit of measurement at the end of the reporting period. Said requirements also include all the comparative information of the financial statements, without modifying the decisions made based on the financial information corresponding to those financial years.

The figures as of December 31, 2021 and 2020, which are presented in these Consolidated Financial Statements for comparative purposes, arise from the restatement to the current unit of measure of the Financial Statements as of said dates, in accordance with IAS 29.

Restatement of the balance sheet

i. Monetary items (those with a fixed nominal value in local currency) are not restated, since they are already expressed in the current unit of measurement at the closing date of the reporting period. In an inflationary period, maintaining monetary assets generates loss of purchasing power and maintaining monetary liabilities generates a gain in purchasing power, provided that such items are not subject to an adjustment mechanism that compensates to some extent for these effects. The monetary loss or gain is included in the result of the period in which it is reported.

ii. The non-monetary items measured at their current values at the end of the reporting period are not restated for the purpose of their presentation in the balance sheet, but the adjustment process must be completed to determine in terms of a homogeneous unit of measurement the results produced by the holding of these non-monetary items.

iii. Non-monetary items measured at historical cost or at a fair value as of a date prior to the closing date of the reporting period are restated by coefficients that reflect the variation in the general price level from the date of acquisition or revaluation to the closing date, proceeding then to compare the restated amounts of those assets with the corresponding recoverable values.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

iv. The restatement of non-monetary assets in the terms of the current unit of measurement at the end of the reporting period without an equivalent adjustment for tax purposes, results in a temporary taxable difference and the recognition of a deferred tax liability whose counterparty is recognized in the result of the period. For the closing of the subsequent period, the deferred tax items are restated for inflation to re-determine the charge to the result of the next period.

v. When the capitalization of costs for loans in non-monetary assets in accordance with IAS 23 is applicable, the portion of those costs that compensate the lender for the effects of inflation is not capitalized.

Restatement of the Comprehensive Income Statement

Revenues and expenses (including interest and foreign exchange differences) are restated from the date of their booking, except for those items of the result that reflect or include in their determination the consumption of assets measured in purchasing power of a date before the consumption booked, which are restated based on the date of origin of the asset to which the item is related (for example, depreciation and other consumption of assets valued at historical cost); and also those results that arise from comparing two measurements expressed in purchasing power currency of different dates, for which it is necessary to identify the amounts compared, restate them separately, and make the comparison, but with the amounts already restated.

The result of the exposure to the change in the purchasing power of the currency (monetary results) is presented in a separate line and reflects the effect of inflation on the monetary items.

Restatement of the statement of changes in equity

As of the transition date (January 1, 2016), the Company applied the following special rules:

i. The components of the capital stock were restated from the dates they were contributed.

ii. Reserved earnings were maintained at the date of transition at their nominal value (legal amount without restatement).

iii. The restated unallocated results were determined by the difference between the net assets restated at the transition date and the rest of the initial equity components expressed as indicated in the preceding sections.

iv. After the restatement at the transition date, all the components of the equity are restated by applying the general price index from the beginning of the period, and each variation of those components is restated from the date of contribution or from the moment in which is added by any other means.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Restatement of the statement of cash flows

IAS 29 requires that all items in this statement should be restated in terms of the current unit of measurement as of the closing date of the period for which it is reported.

The monetary result generated by cash and cash equivalents is presented in the Statement of Cash Flows separately from cash flows from operating, investing and financing activities, as a specific item of the reconciliation between cash and cash equivalents at the beginning and at the end of the year.

4.e) Financial instruments

4.e.1) Financial assets

Recognition and initial measurement

Financial assets are classified, at the time of initial recognition, as:

• Financial assets subsequently measured at amortised cost, and

• Financial assets subsequently measured at fair value (either with changes in other comprehensive income or with changes in results).

The classification of financial assets at initial recognition depends on the financial asset’s contractual cash flow characteristics and the Company’s business model for managing them. For additional information, see Note 16.2.1.

Subsequent measurement

After initial recognition, financial assets are measured according to their initial classification according to the following categories:

Financial assets measured at amortised cost

It is the most relevant category used by the Company, financial assets are classified and measure at amortised cost if both of the following conditions are met:

• The financial asset is held within a business model with the objective to hold financial assets in order to collect contractual cash flows; and

• The contractual terms of the financial asset give rise on specified dates to cash flows that are solely payments of principal and interest on the principal amount outstanding.

Financial assets measured at amortised cost are subsequently measured using the effective interest method.

Gains and losses are recognized in the Statement of Comprehensive Income under financial results when the asset is derecognized, modified or impaired.

Financial assets at fair value through OCI (Debt instruments)

Corresponds to financial assets that are maintained in a business model whose objective is achieved by obtaining contractual cash flows and selling them.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Unrealized gains or losses arising from changes in fair value are recognized as other comprehensive income, except for the accrual of interest, exchange rate difference and the impairment of such assets that are recognized as financial results in the Statement of Comprehensive Income. At the time the asset is written off, the accumulated gain or loss is recognized as a financial result and it is eliminated from the respective reserve.

As of December 31, 2022 and 2021, the Company has not recognized any financial assets under this category.

Financial assets designated at fair value through OCI (equity instruments)

Upon initial recognition, the Company can elect to classify irrevocably its equity investments as equity instruments designated at fair value through OCI when they meet the definition of equity under IAS 32.

Gains and losses on these financial assets are never recycled to profit or loss. Dividends are recognized as other income in the Statement of Comprehensive Income when the right of payment has been established, except when the Company benefits from such proceeds as a recovery of part of the cost of the financial asset, in which case, such gains are recorded in OCI. Equity instruments designated at fair value through OCI are not subject to impairment assessment.

As of December 31, 2022 and 2021, the Company has not recognized any financial assets under this category.

Financial assets at fair value through profit or loss

In the event that financial assets are not classified according to the aforementioned categories, they will be subsequently measured at fair value, presenting gains or losses arising from changes in fair value in the income statement within financial results in the year in which they are originated.

Impairment of financial assets

The Company applies the Expected Credit loss (“ECL”) model for those financial assets accounted for at amortised cost or at fair value through OCI. The ECL is based on the difference between the contractual cash flows due in accordance with the contract and the cash flows that the Company expects to receive, discounted at an approximation of the original effective interest rate. To this end, the Company evaluates various factors, including credit risk, historical trends and other available information.

The application of this model implies recognition of:

• Expected credit losses within of 12 months: these are expected credit losses that result from possible default events within 12 months after the filing date; and

• Expected credit losses during the life of the asset: these are expected credit losses that result from possible events of default during the expected life of a financial instrument.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

In case a loss allowance is recognized, the carrying amount of the asset is reduced through an impairment account and the amount of the loss is presented in the Statement of Comprehensive Income at the time it occurs. Subsequent recoveries of amounts previously written off are credited in the same line item.

The impairment tests performed on accounts receivable are described in Note 4.h.

4.e.2) Financial liabilities

Includes trade payables, loans, other payables and certain payroll and social security taxes payable.

Recognition and initial measurement

Financial liabilities are classified, at initial recognition, as subsequently measured at amortised cost or at fair value through profit or loss, as appropriate.

All financial liabilities are recognized initially at fair value net of transaction costs.

They are classified in current liabilities, except those whose maturity exceeds twelve months, which are classified as non-current liabilities.

Subsequent measurement

Financial liabilities at fair value through profit or loss

Includes financial liabilities measured at fair value. As of December 31, 2022 there are no instruments classified in this category. As of December 31, 2021 the Company includes derivative financial instruments under this category.

Financial liabilities at amortised cost

The Company includes financial liabilities with fixed or determinable payments that are not quoted in an active market. Current liabilities are included, except those whose maturity exceeds twelve months including premiums, discounts and direct expenses, which are included as non-current liabilities. They are measured using the effective interest method. As of December 31, 2022 and 2021, all of the Company’s financial liabilities were classified in this category.

Offsetting of financial instruments

Financial assets and liabilities are offset when there is a legally enforceable right to offset the recognized amounts and there is an intention to settle on a net basis, or realize the asset and settle the liability simultaneously.

4.f) Derivative financial instruments

Derivative financial instruments are recognized at their fair value at inception and subsequently measured at their fair value and disclosed as assets or liabilities depending if it is gain or loss. The results of derivative financial instruments are classified under “Financial income / expenses” in the statement of comprehensive income, or in the other comprehensive income if hedge accounting is applied.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Derivative financial instruments are measured in accordance with IFRS 13 “Fair value measurement”.

The method of recognizing the resulting gain or loss depends on whether the derivative is designated as a hedging instrument or not and, according to the nature of the item being hedged.

As of December 31, 2021, the Company had contracted forward operations for the purchase of US dollars, (which qualify as exchange-traded futures), which are disclosed in the item “Derivative financial instruments” of the Statement of Financial Position, for which the application of the hedge accounting as defined by IFRS 9 has not been elected. The (loss) / gain for the year was included in the line “Derivative financial instruments result” in “Financial Results” in the Statement of Comprehensive Income. For more information, see notes 16.1.1 and 16.1.3 to these financial statements.

4.g) Inventories

Inventories consist of natural gas (in excess of the “Line Pack”, classified as property, plant and equipment) in the Company’s pipeline system, and the liquids stored obtained from natural gas processing at the Cerri Complex.

Inventories are measured at the lower of cost restated for the inflation effects as mentioned in Note 4.d. or net realizable value. Cost is determined using the weighted average cost method. The cost of inventories includes expenditure incurred in purchasing and production and other necessary costs to bring them to their existing location and condition.

The net realizable value is the estimated selling price in the ordinary course of business less the estimated cost of completion and the estimated costs to make the sale.

The assessment of the recoverable value of these assets is made at each reporting date, and the resulting loss is recognized in the statement of comprehensive income when the inventories are overstated.

4.h) Trade receivables and other receivables

Trade receivables are amounts due from customers for goods and services performed in the ordinary course of business. Contract assets are unbilled amounts due to customers related to works in progress.

Trade receivables, contract assets and other receivables are recognized initially at fair value and subsequently measured at amortised cost using the effective interest method, less allowance for trade receivables.

The Company applies the simplified approach to measuring expected credit losses for trade receivables, contract assets and other receivables. For this purpose, customers have been grouped based on shared credit risk characteristics, the existence of guarantees, historical credit losses experienced and the existence of judicial proceedings aimed at obtaining payment. Once each group was defined, an expected uncollectibility rate calculated based on historic default rates adjusted to future economic conditions was defined.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Impairment losses on trade receivables and contract assets are presented as net impairment losses within operating profit. Subsequent recoveries of amounts previously written off are credited against the same line item.

4.i) Cash and cash equivalents

Cash and cash equivalents includes cash in hand, deposits with banking institutions and other short-term, highly liquid investments with original maturities not exceeding three months and without being subject to a risk of a significant change of value.

4.j) Property, plant and equipment (“PPE”)

Assets transferred from the privatization of GdE: The value of these assets was determined based on the price paid for the acquisition of 70% of the Company’s common stock, which amounted to U.S.$ 561.2 million. This price was the basis to determine a total value of common stock of U.S.$ 801.7 million, which, when added to the debt assumed under the Company’s privatization agreement (the “Transfer Agreement”) of U.S.$ 395.0 million, resulted in a total value for PPE of U.S.$ 1,196.7 million. Such value, converted at the exchange rate in effect as of the date of the Transfer Agreement, has been restated for the effects of inflation as mentioned in Note 4.d, and less accumulated depreciation.

Line pack: It represents the natural gas in the transportation system that is necessary to keep the system at operating capacity, valued at acquisition cost and restated for the effects of inflation as mentioned in Note 4.d.

Materials: Materials are recognized at historical cost restated in accordance with Note 4.d. Consumption is restated based on the origin date of the acquisition of the asset.

Other items of PPE: have been valued at acquisition cost restated for the effects of inflation as mentioned in Note 4.d, and net of accumulated depreciation. They include, mainly, all the investments made to achieve system integrity and public safety equal to those required by international standards. Such investments included, among others, the costs of survey programs related to internal and external pipeline inspection, cathodic protection, pipeline replacement and recoating, and the facilities affected to the Production and Commercialization of Liquids and Other Services segment.

PPE additions are recorded at acquisition or construction cost less accumulated depreciation and impairment losses (if applicable), except land, which is recorded at historical cost acquisition minus any impairment (if applicable), all this restated for the effects of inflation as mentioned in Note 4.d. The cost includes the cost of replacing significant components and the borrowing costs derived from loans that finance its construction to the extent that the requirements for recognition as assets are met.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Subsequent costs restated for the effects of inflation as mentioned in Note 4.d. are included in the carrying amount of the asset or recognized as a separate asset, as appropriate, only when it is probable that future economic benefits associated with the item will flow to the Company and the cost of the item can be reliably measured. The carrying amount of a replaced component is written off. In the same way, when a major maintenance is carried out, they are added to the cost of the equipment if the recognition criteria are satisfied, eliminating any remaining non-depreciated remaining value restated for the effects of inflation as mentioned in Note 4.d, if any, of previous overhaul.

In this sense, Resolutions No. 1660/2000 (“Resolution 1660”) and No. 1903/2000 (“Resolution 1903”) issued by ENARGAS include definitions about the costs that should be considered as improvements or maintenance expenses. All other repairs and maintenance are charged to the statement of comprehensive income when incurred.

In accordance with IAS 23, the Company capitalizes financial expense on long term construction projects, until the moment in which the asset is in conditions for its use. Capitalization of borrowing costs is carried out considering the provisions of IAS 29, recording as an expense in the Statement of Comprehensive Income the part of the borrowing costs that compensates for inflation during the same period. As of December 31, 2022 and 2021 there have not been capitalized borrowing costs.

Depreciation related to natural gas transportation assets is computed under the straight -line method over the estimated useful lives of the specific assets, which are not exceeding the maximum useful lives established by ENARGAS through Resolutions 1660 and 1903.

For depreciation of all other PPE, the Company uses the straight-line method of depreciation based on the useful life assigned to each item.

Major maintenance costs are depreciated according to the estimated time until the next major maintenance planned. Regarding the capitalized financial costs, they are depreciated based on the remaining useful lives of those components of PPE that originated such capitalization.

The assets’ residual values and useful lives are reviewed, and adjusted if appropriate, at each reporting date. For further information, see Note 12.

The result generated by the disposal of PPE components is recognized in the year in which it is generated.

Impairment of non-financial assets: The Company assesses at each reporting period whether there is an indication that an individual component or a group of PPE may be impaired.

If any indication exists, the Company estimates the asset´s recoverable amount. An asset´s recoverable amount is the higher of the fair value less costs to sell that asset, and its value-in-use.

That amount is determined for and individual asset, unless the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets; in which case, the cash flows of the group of assets that form part of the cash-generating unit (“CGU”) to which the belong are taken.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Where the carrying amount of an individual asset or CGU exceeds its recoverable amount, the individual asset or CGU, as the case may be, is considered impaired and is written down to its recoverable amount. Impairment losses are recognized in the consolidated statement of comprehensive income.

In assessing value in use, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset for which the estimates of future cash flows have not been adjusted. To such end, the management makes estimates and assumptions of the economic conditions that will prevail throughout the useful life of the assets.

As a result of the factors mentioned above, actual cash flows and values could vary significantly from projected cash flows and the values derived from the discounting techniques used.

Impairment losses, if any, are recognized in the statement of comprehensive income.

As of December 31, 2022 and 2021, the book value of PPE did not exceed its recoverable value.

Infrastructure used in the natural gas transportation service: for its measurement and disclosure, the Company has evaluated the application of Interpretation No. 12 “Service Concession Agreements” (IFRIC 12) that sets the guidelines for the accounting of private entities that provide public services through a service concession agreement or a contract of a similar nature.

Considering the current terms and conditions of the License, tgs concluded that the License is outside the scope of IFRIC 12, as it is considered in substance to provide for an indefinite term because the infrastructure will never revert to the grantor and due to the characteristics of renewal of the License that give a similar result to what which would result from having obtained a perpetual right to operate the infrastructure.

The evaluation carried out and the conclusions reached by tgs are consistent with those of other transportation and natural gas distribution companies in Argentina that are subject to the similar regulations and license agreements. The evaluation was carried out jointly, when the transportation and distribution companies adopted the IFRS in Argentina in 2012, together with the FACPCE, the Buenos Aires Stock Exchange (Bolsas y Mercados Argentinos -“BYMA”) and the CNV, considering the contributions of ENARGAS with respect to the regulatory aspects of the License agreements. In this regard, the CNV issued General Resolution No. 613/2012, ratifying that IFRIC 12 does not apply to natural gas transportation and distribution licenses established under the regulatory framework described in Note 17.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

4.k) Leases

Leases are recognized as a right-of-use asset and a corresponding liability at the date on which the leased asset is available for use by the Company. Each lease payment is allocated between the liability and the finance cost. The finance cost is expensed over the lease term to produce a constant periodic interest rate on the remaining balance of the liability for each period. The right-of-use asset is depreciated over the shorter of the useful life of the asset or the term of the contract.

Assets and liabilities arising from a lease are initially measured based on the present value of the lease. Liabilities include the net present value of the following lease payments:

a) Fixed payments, less any incentive receivable;

b) Variable lease payments;

c) Amounts expected to be collected as a guarantee of the residual value;

d) The exercise price of the lease option; and

e) Penalty payments for termination of the lease.

Lease payments are discounted using the interest rate implicit in the lease. If such rate cannot be determined, the Company’s incremental borrowing rate is used, which is the rate that tgs would have to pay to borrow the funds necessary to obtain an asset of similar value in a similar economic environment.

Right-of-use assets are measured at cost which comprises the following:

a) The amount of the initial measurement of the lease liability;

b) Any lease payments made on or before the commencement date less any lease incentives received;

c) Any initial direct costs; and

d) Restoration costs

These assets, which are subject to the risk of impairment, are depreciated on a straight-line basis over the shorter of the useful life of the leased asset or the lease term.

Payments associated with short-term leases and low-value assets are recognized on a straight-line basis as an expense in the Statement of Income. Short-term leases are those with a term of 12 months or less. Low-value assets comprise computer equipment, vehicles, small items of office furniture and real estate.

The Company has rights to use assets that are shown as part of Property, plant and equipment (see Note 12). Lease liabilities are shown under Financial Debt (see Note 13). For further information regarding the expense related to short-term and low value leases and the interest expense on lease liabilities, see Note 8.j. and 8.k., respectively.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

4.l) Loans

Loans have been initially recorded at fair value net of direct attributable transaction costs. Subsequently, loans are valued at their amortised cost. Liabilities are disclosed as non-current when their maturity exceeds twelve months.

4.m) 
Trade payables

Trade payable are initially recognized at fair value. Subsequently they are measured at amortised cost using the effective tax method.

4.n) Income tax and deferred income tax

Income tax includes current tax and deferred income tax. Income tax is presented in the Statement of Comprehensive Income.

The current income tax is calculated on the basis of tax regulations in force at each reporting period. Management periodically evaluates positions taken in tax returns with respect to situations in which tax regulations are subject to interpretation and establishes provisions if applicable. As of December 31, 2022 and 2021, there are no provisions booked for this concept.

The Company has calculated income tax charges using the deferred tax method, which considers the effect of temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases.

Deferred income tax assets and liabilities are measured at undiscounted nominal value at the tax rates that are expected to apply in the year when the asset is realized or the liability is settled, based on tax rates and tax laws that have been enacted or substantively enacted at the reporting period rate (See Note 14).

A deferred tax is recognized on the temporary differences arising from investments in subsidiaries and associates, except for deferred tax liabilities where the Company is able to control the timing of the reversal of the temporary difference and it is probable that the reversal will not occur in the foreseeable future.

Deferred tax assets and liabilities are offset if the Company has a legally enforceable right to offset recognized amounts and when deferred tax assets and liabilities relate to income tax levied by the same tax authority on the same taxable entity or different taxable entities that intend to settle tax assets and liabilities on a net basis. Deferred tax assets are recognized to the extent that it is probable that future taxable income will be generated against which the temporary differences can be used.

The assets and liabilities generated by the application of the deferred tax were valued at their nominal amount considering the restatements for inflation mentioned in Note 4.d) and are classified as non-current assets or liabilities.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

4.o) Provisions

The Company has recorded provisions related to legal actions, judicial court, claims and administrative proceedings, including interpretive questions of the current legislation and those of regulatory nature.

Provisions for legal claims and/or claims by third parties (“legal claims and others”) are recorded at the expected cancellation value when the Company has a present obligation as a result of a past event, it is probable that an outflow of resources will be required to settle the obligation; and the amount has been reliably estimated. Estimates are reviewed and adjusted, as the Company obtains additional information to be received.

4.p) Revenue recognition from contract with customers

Revenue is measured at the fair value of the consideration received or to be received, and represents amounts receivable for goods and/or services supplied. Revenue is recognized when the control of goods or services is transferred to the customer and the consideration is determined by an amount that reflects the consideration that the Company expects to receive.

Tax on exports and turnover tax are disclosed as Selling Expenses.

The following are the accounting policies of the Company for the recognition of revenue of each of the business segments defined by our management:

Natural Gas Transportation

Natural Gas transportation services includes: (i) firm natural gas transportation, whose revenues are recognized when the capacity is reserved and paid for regardless of actual usage by the customer, (ii) interruptible natural gas transportation and exchange and displacement services whose revenues are recognized when services are rendered and (iii) the operation and maintenance service of the assets affected by the natural gas transportation service corresponding to the expansions promoted by the National Government and whose ownership corresponds to the trusts created for such purpose whose revenues are recognized when services are rendered.

The applicable rates arise from the tariff tables published by ENARGAS. Thus Company’s revenues are recognized by the amount for which it will be entitled to receive as consideration.

At the end of each month, tgs recognizes, over the time, its revenues from sales equivalent to the firm reserved capacity, the volumes of natural gas transported under the modalities of interruptible and exchange and displacement and by the operation and maintenance services. In return, a trade receivable is recognized which represents an unconditional right that the Company has to receive the consideration owed by the customer. On the other hand, the billing of the service is done monthly and according to the guidelines established by ENARGAS, the consideration is received within said calendar month.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Liquids Production and Commercialization

This business segment includes: (i) production and commercialization of liquids on our own account which revenues are recognized in a point in time, and (ii) other liquid services which revenues are recognized over the time.

Liquids Production and Commercialization in the domestic market

In the domestic market, tgs sells the production of propane and butane to LPG retailers in the framework of the programs created by the National Government to supply the domestic market. The sale prices are determined by the ex-Secretary of Hydrocarbon Resources (“SHR”). For more information, see Note 17 - Regulatory framework – b) Regulatory framework for non-regulated segments - to these consolidated financial statements.

The price of those tons of propane and butane that are not sold within the framework of the aforementioned programs is determined by the ex-Ministry of Energy and Mining (“ex MINEM”) based on the international reference prices.

Regarding ethane sales, they are made to PBB Polisur S.R.L. (“PBB”), the only customer to whom this product is sold. To estimate transaction price, the Company uses the most probable amount method. In this regard, the Company only recognizes those transactions where it is highly probable that they will not be reversed in the future.

Liquids Production and Commercialization in the foreign market

In the foreign market, the Company markets propane, butane and natural gasoline to international traders (“traders”) and other clients of worldwide renown, some of them through trucks.

These sales are made under short-term contracts (less than one year), with the price determined as reference to international prices plus / minus a fixed amount per ton sold. There are no variable consideration components in these contracts.

For both domestic and foreign market sales, tgs transfers control and recognizes revenues when the products are delivered to the customer and therefore the product has been accepted and there is no evidence of the existence of pending obligations by the Company. It is at that moment when a trade receivable is recognized given that the receipt of the consideration is unconditional and only the passage of time is the only requirement for receiving the consideration owed by the customer.

Other liquids services

The Liquids production and commercialization segment also comprises reception, storage and dispatch of the liquids from the facilities located in Puerto Galván.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Revenues from sales are recognized when the service is effectively rendered, that is, after the dispatch to each vessel. The price is agreed by the parties being a fixed amount per ton of product dispatched, there being no variable components in them.

These services are billed monthly, at which time an unconditional right to receive the consideration from the client arises.

Subsidies

As part of its participation in propane and butane supply programs in the local market carried out by the National Government, (for more information see “Note 17 - Regulatory Framework - b) Regulatory framework for non-regulated segments”), the Company receives from the Secretary of Energy a series of subsidies that are recognized in accordance with the provisions of IAS 20 “Accounting for government grants and disclosures of government assistance” because they correspond to economic compensations calculated as the difference between the sale prices of the products determined in accordance with the legislation in force and the reference prices calculated by the Secretary of Energy.

Subsidies are recognized at fair value whenever there is reasonable assurance that will be received and that the product has been delivered. They are presented within the caption “Revenues” of the statement of comprehensive income.

Other services

The services included in the Other Services segment consist mainly in (i) treatment, removal of impurities and natural gas compression, including the collection and transport of natural gas (ii) inspection and maintenance of pipelines and compressor plants, (iii) services of steam generation for electricity production and management services for expansion works and steam generation for the production of electricity and (iv) natural gas transportation services in Vaca Muerta.

Revenues from sales of this business segment are recognized over the time in the period in which the service is provided. The sale price is determined according to what arises from the contractual conditions agreed between tgs and its customers. In all cases, the recognition and billing of sales income is made on a monthly basis so that at that time a sales credit is recorded.

Revenues from the participation in the joint venture, which correspond to the construction activities provided by the joint venture, are recognized based on the stage of completion of the contractual activity (percentage of completion method), considering the estimated final margin of the work. To apply the percentage of completion method, the revenue recognized at the end of the period will correspond to the total contractual revenue multiplied by the actual percentage of completion, based on the proportion of the total direct contractual costs incurred to date, and the total direct contractual costs, including the estimated costs to complete the construction. Costs incurred in excess of the costs associated with revenue are recognized in Contract assets.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Telecommunications

Revenues from the provision of Telecommunications services are recognized in the statement of comprehensive income at the time of effective performance of the service. The sale price is determined according to what arises from the contractual conditions agreed between tgs and its customers. The consideration is determined as a fixed monthly amount. In all cases, the recognition and billing of sales income is made on a monthly basis so that at that time a sales receivable is recorded.

Financial components

The Company does not have any contracts where the period between the transfer of the promised goods or services to the customer and payment by the customer exceeds one year. As a consequence, the Company does not adjust any of the transaction prices for the time value of money.

4.q) Contract liabilities

Mainly consist of pre-payments for services made by customers in order to finance the works to render the service. Contract liabilities are recognized initially at their fair value. Subsequent to initial recognition, advances from customers are measured at their amortised cost based on the projections of the services to be provided that cancel the advances, restated for the inflation effects as mentioned in Note 4.d).

Additionally, it includes the advance received by the UT from the Argentine Government as payment on account of the gas pipeline construction project. For more information, see “Note 23 - Associates and joint arrangements.”

4.r) Equity accounts

The activity in the Equity accounts reflects resolutions adopted by Shareholders in their meetings, or the effects of the laws or regulations in force. The equity accounts are restated for the inflation effects according to what is mentioned in Note 4.d), except the account Capital stock which is maintained at its original value.

Common stock and adjustment to common stock

The common stock consists of contributions made by shareholders represented by shares and comprises outstanding shares at their face value, net of treasury shares mentioned below.

Common stock accounts were restated in constant currency as mentioned in Note 4.d). Common stock account was kept at original value and the adjustment arising from such restatement is shown under “Inflation Adjustment to common stock”.

Common stock adjustment is not distributable in cash or in kind but may be capitalized through issuance of shares. In addition, this balance may be used to compensate accumulated losses.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Treasury shares and adjustments to treasury shares

Corresponds to the reclassification of the nominal value and corresponding restatement in constant peso (Inflation Adjustment to Common Stock) of shares issued and repurchased by the Company in market transactions, as required by the current regulations of the CNV.

Own equity instruments that are reacquired (treasury shares) are recognized at cost restated for the inflation effects as mentioned in Note 4.d), and deducted from equity. No gain or loss is recognized on the purchase, sale or cancellation of the Company’s treasury shares. Any difference between the carrying amount and the consideration, if reissued, is recognized as a premium on common stock or additional paid-up capital.

Additional paid-up capital

Corresponds to the difference between the carrying value of the treasury shares and the quoted value at the time were distributed (for more information see Note 19.b). It is restated according to what is mentioned in Note 4.d).

Legal Reserve

Pursuant to the provisions of the Argentine Business Association Law and the CNV, the Company is required to set up a legal reserve by providing at least 5% of the aggregate amount of net income for the year, prior year adjustments, transfers of other comprehensive income to retained earnings and accumulated losses of prior years, when this aggregate amount exceeds zero until the legal reserve equals 20% of the sum of Capital stock and Adjustment to capital stock balances.

Distribution of dividends

The cash dividend is recognized as a liability in the Company’s financial statements in the year in which they are approved by the shareholders of the Company or the Board of Directors according to the powers delegated by the Shareholders’ Meeting, as appropriate.

Retained earnings

The outstanding balance of retained earnings includes accumulated gains or losses which were not allocated to a specific purpose reserve and, when positive, may be distributed pursuant to the decision of the Shareholders provided these retained earnings are not subject to legal restrictions, as mentioned above “Legal reserve”.

4.s) Basic and diluted earnings per share

Earnings per share as of December 31, 2022, 2021 and 2020 were calculated as follows:

	2022		2021		2020
Net income attributable to owners of the Company		32,317,790		40,772,306		9,662,187
Average number of outstanding shares (1)		752,761,058		752,761,058		762,371,755
Basic and diluited earnings per share		42.93		54.16		12.68

⁽¹⁾ The weighted average number of shares considers the effect of the weighted average of the changes originated in the transactions with the treasury shares made during the year.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

As of December 31, 2022, 2021 and 2020, there are no tgs instruments outstanding that imply the existence of potential ordinary shares, thus the basic net income per share for each of the three years ended on December 31, 2022, 2021 and 2020 matches the diluted net income per share.

5. CRITICAL ACCOUNTING ESTIMATES AND JUDGMENTS

The preparation of financial statements in conformity with professional accounting standards requires the Company to make accounting estimates that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The making of such estimates involves tgs using assumptions and presumptions that are based on a number of factors, including past trends, events known at the date of issuance of these financial statements, and expectations of future events and their outcomes.

5.a) Impairment of PPE

As mentioned in Note 4.j), the management periodically evaluates the existence of significant events or changes that could have an adverse effect on the Company or will take place in the near future that could affect the recoverable amount of PPE. PPE is tested to assess whether an impairment or reversal of a previous impairment is required when significant changes took place during the period, or that will take place in the near future, indicate that the recoverable value of the PPE amounts may be affected. These evaluations are performed at the lowest level for which identifiable cash flows exist, i.e., for each CGU. The management considers each business segment as a CGU.

When assessing whether an impairment indicator may exist, tgs evaluates both internal and external sources of information, such as the following:

• Whether significant decreases in the market values of PPE elements took place.

• Whether prices of the main products and services that are marketed decreased.

• Whether significant changes in the regulatory framework were introduced.

• Whether operating costs suffered a materially increase.

• Whether evidence of obsolescence or physical damage has occurred.

• Whether the macroeconomic situation in which tgs carries out its activities, including significant variations in the sale prices of products, raw materials, interest rates, etc, has worsen.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Since August 2019, the main macroeconomic and business variables in Argentina suffered a significant deterioration. This situation was aggravated in 2020 by the negative consequences that COVID had on Argentina’s economic situation which led the Argentine Government to take a series of measures even affecting the regulatory framework of the natural gas transportation segment (see Notes 1 and 17). Given these indicators of impairment of the book value of PPE, the recoverable value of Natural Gas Transportation segment CGU has been calculated based on its value in use as of December 31, 2022.

The value in use of PPE is sensitive to significant variation in the assumptions applied, including the determination of future tariffs determined by the Argentine Government in the Natural Gas Transportation segment.

The value in use is calculated based on the basis of discounted future cash flows. The projected cash flows are prepared taking into account significant assumptions relating to: discount rate, estimates of future tariff adjustments and the recognition of cost adjustments, and expected macroeconomic variables such as interest rates, inflation, foreign exchange rates, among others. The discount rate is based on a weighted average cost of capital (“WACC”).

In performing the analysis for the Natural Gas Transportation segment, the management considered among others: (i) the status of the negotiations with the Argentine Government, (ii) the contractual rights derived from the License, (iii) Management´s expectations with respect to the transitional tariff increase to be granted until the new RTI is finalized, (iv) Management´s expectation of the outcome of the new RTI process and (v) the impact of a cost monitoring scheme that allows for semi-annual adjustments to current tariffs.

The management has prepared, for the Natural Gas Transportation segment, three different estimates of the expected cash flows by sensitizing its main variables (as described above) and assigning probabilities of occurrence based on experience and considering the current socio-economic context, as follows:

a) Base scenario: probability of occurrence assigned 65%

b) Optimistic scenario: probability of occurrence assigned 20%.

c) Pessimistic scenario: probability of occurrence assigned  15%.

In order to make the comparison between the expected cash flow and the book value of the assets assigned to the Natural Gas Transportation segment, the Company has used a weighting of the scenarios, in accordance with the probabilities mentioned above, to determine the expected value in use.

As of December 31, 2022 and 2021, based on the foregoing, the management has not determined the need to record an additional impairment charge.

During 2020, we recorded an impairment of Ps. 9,155 million on our Natural Gas Transportation segment fixed assets as a consequence of the impairment test.

As of December 31, 2022, the Company’s book value of PPE related to Natural Gas Transportation cash-generating units amounted Ps. 189,314,745.

The estimated recoverable amounts of PPE items are sensitive to significant variation in the assumptions applied. In either case, there can be no assurance with certainty that the actual cash flows arising from these circumstances will be in line with the assumptions applied in determining the values in use. Therefore, significant differences could arise in the future in relation to the estimated values in use.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

5.b) Provisions for legal and other claims

The Company has recorded certain contingent liabilities related to legal, judicial or extrajudicial actions, claims and administrative proceedings, including those of a legal and regulatory nature. The Company records liabilities when their occurrence is probable and when a reliable estimate of their amount can be made. Provisions are based on events known to the Company at the date of issuance of its financial statements, their probability of occurrence, its estimates of the outcome of such matters and the experience of its legal advisors in contesting, litigating and settling other matters. To the extent that there are more elements of judgment that allow improving the evaluation of contingencies, there will be changes in the estimates of future charges, which could have an impact on the Company’s future results and its economic and/or financial situation.

5.c) Income tax

Deferred tax assets are recognized for all tax loss carryforwards to the extent that it is probable that there will be a taxable profit against which the tax loss can be utilized. Determining the amount of deferred tax assets that can be recognized requires significant judgments to be made by management based on the likely timing and level of future tax benefits, together with future tax planning strategies and macroeconomic variables that impact the business.

On December 29, 2017, the PEN enacted and put into effect through Decree 1112/2017 a tax reform sanctioned in the National Congress through Law No. 27,430 (the “Tax Reform”) whereby a decrease in tax rates was determined. Subsequently, through the enactment of the Law of Social Solidarity and Productive Reactivation in the Framework of Public Emergency No. 27,541 (“Solidarity Law”), the Argentine Government defined the postponement of the reduction of the current tax rate for fiscal years beginning on or after January 1, 2021.

On June 16, 2021, “Law No. 27,630: Amending the Income Tax Law” was published in the Official Gazette which, among other issues, introduces a modification in the income tax rate effective for fiscal years or fiscal years beginning on or after January 1, 2021. The amendment establishes a tiered system of rates in three segments according to the level of accumulated net taxable income: a first step of 25% for accumulated net income up to $ 5 million pesos; the second step of 30% for accumulated net income between $ 5 and $ 50 million pesos; and a last segment of 35% for accumulated net income over $ 50 million pesos. The amount of accumulated net profits will be adjusted annually, starting January 1, 2022, considering the annual variation of the CPI provided by INDEC.

For the determination of the deferred and current income tax charge as of December 31, 2022 and 2021, the Company has applied the progressive tax rate in force as mentioned above.

More detailed information on income tax is included in Note 14 “Income tax and deferred income tax”.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

6. SUPPLEMENTAL CASH FLOW INFORMATION

For purposes of the consolidated statement of cash flows, the Company considers all highly liquid temporary investments with an original maturity of three months or less at the time of purchase to be cash equivalents. The Cash Flow Statement has been prepared using the indirect method, which requires a series of adjustments to reconcile net income for the period to net cash flows from operating activities.

Non-cash investing and financing activities for the years ended December 31, 2022, 2021 and 2020 are presented below:

	2022		2021		2020
Unpaid acquisition of PPE		1,846,947		1,856,040		895,394
Principal payment of financial lease (1)		901,526		1,163,922		561,495

⁽¹⁾ Cancelled through compensation with trade receivables with the creditor. See Note 13.

Note 13 to these consolidated financial statements includes a reconciliation between the initial and final balance of the financial liabilities arising from financing activities.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

7. CONSOLIDATED BUSINESS SEGMENT INFORMATION

IFRS 8 “Operating Segments” requires an entity to report financial and descriptive information about its reportable segments, which are operating segments or aggregations of operating segments that meet specified criteria. Operating segments are components of an entity about which separate financial information is available that is evaluated regularly by the CODM in deciding how to allocate resources and in assessing performance. The Company’s CODM is the Board of Directors.

The Company analyzes its businesses into four segments: (i) Natural Gas Transportation Services, subject to ENARGAS regulations, (ii) Liquids Production and Commercialization, (iii) Other Services including midstream, among others, and (iv) Telecommunications. These last three business segments are not regulated by ENARGAS. Production and Commercialization of Liquids segment is regulated by the SE.

Detailed information on each business segment for the years ended December 31, 2022, 2021 and 2020 is disclosed below:

Year ended December 31, 2022
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenues from sales		40,643,462			104,214,859			18,747,054			919,414			-			164,524,789
Intersegment revenues		1,164,760			-			-			-			(1,164,760	)		-
Cost of sales		(29,357,094	)		(58,784,800	)		(8,407,580	)		(656,850	)		1,164,760			(96,041,564	)
Administrative expenses		(4,230,811	)		(829,258	)		(627,243	)		(67,121	)		-			(5,754,433	)
Selling expenses		(3,019,249	)		(5,737,983	)		(1,336,806	)		(109,559	)		-			(10,203,597	)
Other operating results		(180,352	)		37,940			65,914			-			-			(76,498	)
Operating profit		5,020,716			38,900,758			8,441,339			85,884			-			52,448,697
Depreciation of property, plant and equipment		(14,385,464	)		(1,308,511	)		(3,878,694	)		-			-			(19,572,669	)

	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		224,390,925		79,765,071		102,867,810		5,068,419		412,092,225
Identifiable liabilities		68,642,296		7,941,685		63,768,842		4,515,113		144,867,936

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Year ended December 31, 2021
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenue from sales		47,729,944			108,559,750			16,137,635			892,492			-			173,319,821
Intersegment revenues		1,753,852			-			-			-			(1,753,852	)		-
Cost of sales		(30,398,565	)		(56,280,587	)		(7,294,631	)		(623,473	)		1,753,852			(92,843,404	)
Administrative expenses		(3,820,247	)		(664,124	)		(465,910	)		(45,786	)		-			(4,996,067	)
Selling expenses		(3,353,756	)		(4,889,198	)		(1,010,116	)		(86,494	)		-			(9,339,564	)
Other operating results		(396,796	)		626,862			20,099			760			-			250,925
Operating profit		11,514,432			47,352,703			7,387,077			137,499			-			66,391,711
Depreciation of property, plant and equipment		(13,844,172	)		(1,194,842	)		(3,682,135	)		-			-			(18,721,149	)

			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		242,560,322		74,892,859		87,327,237		739,498		405,519,916
Identifiable liabilities		78,050,198		21,404,091		70,954,650		204,490		170,613,429

Year ended December 31, 2020
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenue from sales		69,100,376			81,140,913			12,832,687			1,201,467			-			164,275,443
Intersegment revenues		2,483,327			-			-			-			(2,483,327	)		-
Cost of sales		(29,218,827	)		(46,554,104	)		(6,938,313	)		(821,874	)		2,483,327			(81,049,791	)
Administrative expenses		(3,652,010	)		(746,192	)		(512,372	)		(37,239	)		-			(4,947,813	)
Selling expenses		(4,290,739	)		(3,457,748	)		(881,361	)		(96,031	)		-			(8,725,879	)
Other operating (expenses) / income		(129,779	)		411,530			7,383			4,388			-			293,522
Impairment of PPE		(9,156,072	)		-			-			-			-			(9,156,072	)
Operating profit		25,136,276			30,794,399			4,508,024			250,711			-			60,689,410
Depreciation of property, plant and equipment		(13,415,586	)		(1,125,453	)		(3,574,463	)		-			-			(18,115,502	)

			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		243,316,895		52,023,450		82,037,118		720,848		378,098,311
Identifiable liabilities		81,196,369		15,989,754		86,567,711		210,291		183,964,125

8. DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS

a) Other receivables

	2022				2021
	Current		Non Current		Current		Non Current
Turnover tax balance		220,927		-		246,803		-
Income tax credit balance		96,687		-		42,697		-
VAT credit balance		1,495,500		-		1,368,925		-
Other tax receivables		107,249		55		73,562		919
Prepaid expenses		1,524,421		-		814,670		-
Advances to suppliers		8,338,576		-		5,887,123		-
Subsidies receivables		3,768,159		-		2,427,450		-
Other Receivables UT		33,460		-		56,924		-
Others		591,659		14,844		724,109		16,330
Total		16,176,638		14,899		11,642,263		17,249

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

b) Trade receivables

	2022					2021
	Current			Non Current		Current			Non Current
Commons		15,741,345			-		20,256,312			-
UT		9,448			-		205,075			-
Natural Gas Transportation		4,398,150			-		6,681,903			-
Production and Commercialization of Liquids		8,189,884			-		10,793,068			-
Other services		3,143,863			-		2,576,266			-
Related parties (Note 21)		1,330,471			-		695,684			-
Natural Gas Transportation		131,145			-		158,708			-
Production and Commercialization of Liquids		281,774			-		210			-
Other services		917,552			-		536,766			-
Allowance for doubtful accounts		(132,521	)		-		(258,142	)		-
Total		16,939,295			-		20,693,854			-

The movement of the allowance for doubtful accounts is as follows:

Balances as of December 31, 2020	389,643
Inflation adjustment restatement	(131,501	)
Additions	-
Applications	-
Reversals	-
Balances as of December 31, 2021	258,142
Inflation adjustment restatement	(125,621	)
Additions	-
Applications	-
Reversals	-
Balances as of December 31, 2022	132,521

c) Cash and cash equivalents

	2022		2021
Cash and banks		289,630		213,984
UT Cash and banks		159		142
Mutual funds in local currency		2,654,934		8,138,623
Interest-bearing accounts		33,343		214,906
UT Mutual funds		10,880		59,349
Total		2,988,946		8,627,004

d) Contract liabilities

	2022				2021
	Current		Non Current		Current		Non Current
Natural Gas Transportation		360,887		5,902,032		360,886		6,262,944
Production and Commercialization of Liquids		345,243		557,671		263,596		902,915
Other services		326,802		5,257,709		327,971		3,797,298
UT		12,522		-		26,122		-
Total		1,045,454		11,717,412		978,575		10,963,157

During 2022 and 2021 financial years, the Company recognized Ps. 469,978 and Ps. 477,516, respectively, in revenues for sales from contracts with clients in the Statement of Comprehensive Income, which had been included in the balance at the beginning of each year.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Revenues related to the contract liabilities will be recognized in the Statement of Comprehensive Income in accordance with the schedule stipulated with the customers for the provision of the service, which will be completed between 2025 and 2053.

e) Other payables

	2022				2021
	Current		Non Current		Current		Non Current
Payable for compensation for the Board of Directors and Supervisory Committee		68,039		-		37,809		-
Others		1,763		-		1,983		-
UT Other liabilities		216,753		-		580,178		-
Total		286,555		-		619,970		-

f) Taxes payables

	2022				2021
	Current		Non Current		Current		Non Current
Health and safety tax		52,339		-		41,921		-
Withholdings and perceptions made to third parties		581,800		-		621,114		-
Turnover Tax		158,382		-		267,965		-
Tax on exports		103,759		-		337,941		-
Others		48,416		14,285		28,485		-
Total		944,696		14,285		1,297,426		-

g) Trade payables

	2022				2021
	Current		Non Current		Current		Non Current
Suppliers		9,717,662		-		10,662,184		-
UT Suppliers		119,077		-		129,333		-
Customers (credit balances)		15,237		-		18,778		-
Related companies (Note 21)		672,960		-		1,010,388		-
Total		10,524,936		-		11,820,683		-

h) Revenues

	2022		2021		2020
Sales of goods and services		159,116,112		169,132,295		163,311,441
Subsidies		5,408,677		4,187,526		964,002
Total		164,524,789		173,319,821		164,275,443

Disaggregation of revenues

Below is a table in which revenues are disaggregated considering the type of market and the opportunity to satisfy performance obligations:

Year ended December 31, 2022
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		46,313,662		-		-		46,313,662
Local market		40,643,462		57,901,197		18,747,054		919,414		118,211,127
Total		40,643,462		104,214,859		18,747,054		919,414		164,524,789
Timing of revenue recognition:
Over the time		40,643,462		4,504,128		18,747,054		919,414		64,814,058
At a point in time		-		99,710,731		-		-		99,710,731
Total		40,643,462		104,214,859		18,747,054		919,414		164,524,789

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Year ended December 31, 2021
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		44,708,635		-		-		44,708,635
Local market		47,729,944		63,851,115		16,137,635		892,492		128,611,186
Total		47,729,944		108,559,750		16,137,635		892,492		173,319,821
Timing of revenue recognition:
Over the time		47,729,944		4,786,166		16,137,635		892,492		69,546,237
At a point in time		-		103,773,584		-		-		103,773,584
Total		47,729,944		108,559,750		16,137,635		892,492		173,319,821

Year ended December 31, 2020
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		28,033,885		-		-		28,033,885
Local market		69,100,376		53,107,028		12,832,687		1,201,467		136,241,558
Total		69,100,376		81,140,913		12,832,687		1,201,467		164,275,443
Timing of revenue recognition:
Over the time		69,100,376		4,898,351		12,832,687		1,201,467		88,032,881
At a point in time		-		76,242,562		-		-		76,242,562
Total		69,100,376		81,140,913		12,832,687		1,201,467		164,275,443

Detailed information of revenues on each business segment for the years ended December 31, 2022, 2021 and 2020 is disclosed below:

i. Natural Gas Transportation:

	2022		2021		2020
Firm		33,984,311		38,806,353		56,118,114
Access and Charge		1,409,911		1,680,113		2,469,413
Interruptible and Others		5,249,240		7,243,478		10,512,849
Total		40,643,462		47,729,944		69,100,376

ii. Production and Commercialization of Liquids:

	2022		2021		2020
Product		94,302,054		99,586,058		75,278,560
Services		4,504,128		4,786,166		4,898,351
Government grants		5,408,677		4,187,526		964,002
Total		104,214,859		108,559,750		81,140,913

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

iii. Other services:

	2022		2021		2020
Conditioning and treatment		5,941,496		6,509,010		5,989,222
Operation and maintenance		450,840		481,338		490,937
Steam sales		372,779		429,014		535,488
Construction		2,363		87,610		75,893
UT Construction		43,537		79,694		207,231
Transportation and conditioning of Natural Gas		11,717,321		8,137,078		5,274,364
Others		218,718		413,891		259,552
Total		18,747,054		16,137,635		12,832,687

i) Net cost of sales

	2022			2021			2020
Inventories at the beginning of the year		2,278,309			1,680,352			1,231,440
Purchases		48,129,536			46,041,630			37,255,612
Operating costs (Note 8.j.)		47,467,264			47,399,731			44,243,091
Inventories at the end of the year		(1,833,545	)		(2,278,309	)		(1,680,352	)
Total		96,041,564			92,843,404			81,049,791

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

j) Expenses by nature – Information required under art. 64 paragraph I, clause B) Commercial Companies Law

	2022
			Operating expenses
Accounts	Total		Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other compensations		13,296,943		5,584,104		4,529,381		2,438,849		744,609			-
Social security taxes		2,521,317		1,034,058		890,630		441,721		154,908			-
Compensation to Directors and Supervisory Committee		125,897		-		-		125,897		-			-
Professional services fees		1,644,291		48,972		600,631		898,431		96,257			-
Technical operator assistance fees		3,067,198		280,709		2,786,489		-		-			-
Materials		1,594,685		462,672		1,130,811		-		1,202			-
Third parties services		1,563,456		679,466		688,730		195,260		-			-
Telecommunications and post expenses		84,443		16,128		26,623		36,931		4,761			-
Rents		108,981		17,579		80,773		9,653		976			-
Transports and freight		613,856		349,132		252,357		11,993		374			-
Easements		200,955		156,726		44,229		-		-			-
Offices supplies		46,944		18,548		9,598		17,996		802			-
Travels expenses		198,078		102,338		35,091		46,229		14,420			-
Insurance		687,743		398,963		237,271		51,509		-			-
Property, plant and equipment maintenance		6,464,178		5,111,188		1,274,298		78,692		-			-
Depreciation of property, plant and equipment		19,572,669		13,185,736		5,187,205		1,199,728		-			-
Taxes and contributions		10,858,003		1,786,426		60,885		29,609		8,981,083	(1)		-
Advertising		189,091		-		-		-		189,091			-
Banks expenses		99,346		-		-		99,346		-			-
Interests expense		6,798,475		-		-		-		-			6,798,475
Foreign exchange loss		52,105,975		-		-		-		-			52,105,975
Costs of services rendered to third parties		48,922		-		48,922		-		-			-
Other expenses		438,298		124,348		226,247		72,589		15,114			-
Total 2022		122,329,744		29,357,093		18,110,171		5,754,433		10,203,597			58,904,450

⁽¹⁾ Includes tax on exports for Ps. 3,659,451 for the year ended December 31, 2022.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

	2021
				Operating expenses
Accounts	Total			Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other contributions		11,614,557			5,027,119		3,883,677		2,072,132		631,629			-
Social security taxes		2,355,744			1,047,791		820,929		341,671		145,353			-
Compensation to Directors and Supervisory Committee		124,190			-		-		124,190		-			-
Professional services fees		996,024			70,276		103,990		781,403		40,355			-
Technical operator assistance fees		4,250,358			744,106		3,506,252		-		-			-
Materials		1,601,348			531,421		1,069,880		-		47			-
Third parties services		1,414,519			662,460		673,542		78,517		-			-
Telecommunications and post expenses		94,968			18,745		18,309		48,768		9,146			-
Rents		61,124			28,263		16,423		15,554		884			-
Transports and freight		496,898			287,470		201,379		7,712		337			-
Easements		355,420			334,008		21,412		-		-			-
Offices supplies		38,629			13,620		8,481		14,812		1,716			-
Travels expenses		109,433			60,943		21,137		22,368		4,985			-
Insurance		852,181			495,149		298,049		58,983		-			-
Property, plant and equipment maintenance		7,814,946			6,598,364		1,134,931		81,651		-			-
Depreciation of property, plant and equipment		18,721,149			12,564,973		4,876,977		1,279,199		-			-
Taxes and contributions		10,433,607			1,809,784		74,808		32,406		8,516,609	(1)		-
Advertising		103,548			-		-		-		103,548			-
Doubtful accounts		(129,715	)		-		-		-		(129,715	)		-
Banks expenses		23,340			-		-		23,340		-			-
Interests expense		8,703,402			-		-		-		-			8,703,402
Foreign exchange loss		24,239,337			-		-		-		-			24,239,337
Costs of services rendered to third parties		111,952			-		111,952		-		-			-
Other expenses		291,142			104,070		159,041		13,361		14,670			-
Total 2021		94,678,101			30,398,562		17,001,169		4,996,067		9,339,564			32,942,739

⁽¹⁾ Includes tax on exports of Ps. 3,069,765 for the year ended December 31, 2021.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

	2020
			Operating expenses
Accounts	Total		Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other compensations		11,910,337		5,332,943		3,720,628		2,180,423		676,343			-
Social security taxes		2,422,583		1,044,064		744,398		487,600		146,521			-
Compensation to Directors and Supervisory Committee		117,725		-		-		117,725		-			-
Professional services fees		929,950		101,483		39,103		708,924		80,440			-
Technical operator assistance fees		4,205,901		1,733,124		2,472,777		-		-			-
Materials		1,332,039		482,988		849,051		-		-			-
Third parties services		1,523,368		692,579		772,421		56,718		1,650			-
Telecommunications and post expenses		139,427		39,218		30,941		61,112		8,156			-
Rents		74,086		29,685		15,245		26,924		2,232			-
Transports and freight		460,821		273,192		180,073		7,556		-			-
Easements		289,449		257,489		31,960		-		-			-
Offices supplies		26,629		9,077		3,787		12,962		803			-
Travels expenses		200,878		90,310		58,722		44,430		7,416			-
Insurance		752,400		431,938		267,609		52,812		41			-
Property, plant and equipment maintenance		5,505,454		4,733,387		676,821		95,246		-			-
Depreciation of property, plant and equipment		18,115,502		12,414,245		4,699,917		1,001,340		-			-
Taxes and contributions		8,830,693		1,487,002		76,682		3,758		7,263,251	(1)		-
Advertising		252,851		-		-		-		252,851			-
Doubtful accounts		279,520		-		-		-		279,520			-
Banks expenses		69,783		-		-		69,783		-			-
Interests expense		9,874,146		-		-		-		-			9,874,146
Foreign exchange loss		43,621,645		-		-		-		-			43,621,645
Costs of services rendered to third parties		319,508		-		319,508		-		-			-
Other expenses		157,879		66,103		64,621		20,500		6,655			-
Total 2020		111,412,574		29,218,827		15,024,264		4,947,813		8,725,879			53,495,791

⁽¹⁾ Includes tax on exports for Ps. 1,238,347 for the year ended December 31, 2020.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

k) Net financial results

	2022			2021			2020
Financial income
Interest income		1,834,401			1,543,011			1,607,135
Foreign exchange gain		27,942,306			11,843,541			14,609,528
Subtotal		29,776,707			13,386,552			16,216,663
Financial expenses
Interest expense (1)		(6,798,475	)		(8,703,402	)		(9,874,146	)
Foreign exchange loss		(52,105,975	)		(24,239,337	)		(43,621,645	)
Subtotal		(58,904,450	)		(32,942,739	)		(53,495,791	)
Other financial results
Notes repurchase results		(1,030,169	)		(806,841	)		1,174,202
Derivative financial instruments results		(127,585	)		(157,227	)		1,321,859
Fair value gains / (losses) on financial instruments through profit or loss		24,127,905			2,319,880			(21,362,711	)
Others		(770,571	)		(960,662	)		(1,052,827	)
Subtotal		22,199,580			395,150			(19,919,477	)
Gain on net monetary position		3,768,283			18,311,140			19,058,813
Total		(3,159,880	)		(849,897	)		(38,139,792	)

⁽¹⁾ Includes Ps. 382,649, Ps. 568,315 and Ps. 712,528 of accrued interest corresponding to leasing liabilities, for the years ended December 31, 2022, 2021 and 2020.

l) Other operating results

	2022			2021			2020
Net increase in provisions (1)		(356,890	)		(612,036	)		(453,946	)
Recovery of insurance		29,000			730,846			696,771
Recovery action of VAT and income tax (Note 20.c)		-			144,912			-
Others		251,392			(12,797	)		50,697
Total		(76,498	)		250,925			293,522

⁽¹⁾ Including legal expenses

m) Financial assets measured at amortized cost

	2022				2021
	Current		Non Current		Current		Non Current
Fixed term deposits in foreign currency		-		39,290,345		-		43,718,093
VRD bonds		1,438		-		3,721		2,306
Private debt bonds		-		871,938		-		-
Total		1,438		40,162,283		3,721		43,720,399

n) Financial assets at fair value through profit or loss

	2022				2021
	Current		Non Current		Current		Non Current
Mutual funds in local market		-		-		152,868		-
Public debt bonds		7,162,504		-		6,432,817		-
Private debt bonds with related parties		2,570,796		-		1,388,558		-
Private debt bonds		25,808,410		-		17,870,749		-
Equity instruments		3,747,920		-		-		-
Total		39,289,630		-		25,844,992		-

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

o) Payroll and social security taxes payable

	2022				2021
	Current		Non Current		Current		Non Current
Vacation benefit payable		1,296,356		-		1,186,142		-
Annual bonus payable		857,151		-		896,347		-
Social security taxes payable		471,945		-		685,123		-
UT		4,377		-		6,957		-
Total		2,629,829		-		2,774,569		-

9. INVESTMENTS IN ASSOCIATES

	2022						2021
	Description of securities
	Face		Amount		Book value		Book value
Name and issuer	value
Transporte y Servicios de Gas en Uruguay S.A.	Ps. Uru. 1			196,000		13,502		19,339
Emprendimientos de Gas del Sur S.A. (in liquidation)	$	1		116,130		700		1,132
Gas Link S.A.	$	1		502,962		140,300		43,900
Total						154,502		64,371

10. JOINT ARRANGEMENTS

tgs jointly with SACDE applied for the public tender launched by the Argentine Government for the construction of a connection pipeline in the province of Santa Fe. This tender was finally obtained by the UT whose sole purpose is the execution of such works. For further information, see Note 23.

The Company participates in the UT in a percentage of 51% on the rights of the assets and on the obligations related to them. tgs consolidates line by line assets, liabilities and results of the UT based on the aforementioned percentage of participation.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The breakdown of the amounts included in the statements of financial position related to the Company’s participation in the UT and its results is the following:

	2022		2021
Consolidated Statements of financial position
Non Current assets		-		-
Current Assets		72,020		368,325
Total		72,020		368,325
Non Current Liabilities		-		-
Current Liabilities		278,622		739,043
Total		278,622		739,043

	2022			2021			2020
Consolidated Statements of comprehensive income
Gross profit		27			53			13,415
Operating loss		(7,854	)		(15,299	)		(3,719	)
Net Financial results		141,140			274,931			220,157
Comprehensive income		133,286			259,632			216,438

11. SHARE OF PROFIT FROM ASSOCIATES

	2022			2021			2020
EGS (in liquidation)		(432	)		(308	)		(232	)
TGU		(5,837	)		(5,770	)		(1,418	)
Link		96,407			47,425			64,307
Total		90,138			41,347			62,657

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

12. PROPERTY, PLANT AND EQUIPMENT

	2022
	Cost												Depreciation and Impairment
													Accumulated at									Accumulated at
	Beginning										End of the		the beginning									the end		Net
Account	of the year		Additions		Retirements			Transfers			year		of the year		Retirements			For the year		rate %		of the year		book value
Pipelines		265,066,631		-		-			4,361,804			269,428,435		144,855,499		-			6,548,184		2.2		151,403,683		118,024,752
Compressor plants		116,840,361		-		-			4,135,224			120,975,585		80,652,592		-			5,284,061	3.3 to 25			85,936,653		35,038,932
Other plants		106,030		-		-			-			106,030		46,113		-			3,289		3.3		49,402		56,628
Stations of regulation and/or measurement of pressure		9,502,577		-		-			165,914			9,668,491		7,489,062		-			260,160		4.0		7,749,222		1,919,269
Other technical installations		1,964,446		-		-			420,266			2,384,712		1,542,316		-			73,079		6.7		1,615,395		769,317
Subtotal assets related to natural gas transportation service		393,480,045		-		-			9,083,208			402,563,253		234,585,582		-			12,168,773				246,754,355		155,808,898
Non-regulated segment Pipelines		43,520,177		-		-			185,982			43,706,159		3,383,838		-			1,444,820		2.2		4,828,658		38,877,501
Non-regulated segment Compressor plants		8,422,007		-		-			72,584			8,494,591		4,969,891		-			870,535	3.3 to 25			5,840,426		2,654,165
Non-regulated segment Other plants		77,586,306		-		(1,863,128	)		10,121,226			85,844,404		44,982,655		(1,863,128	)		2,220,735		3.3		45,340,262		40,504,142
Non-regulated segment Stations of regulation and/or measurement of pressure		2,829,148		-		-			3,603			2,832,751		384,512		-			111,187		4.0		495,699		2,337,052
Non-regulated segment Other technical installations		1,040,891		-		-			47,379			1,088,270		577,826		-			90,090		6.7		667,916		420,354
Subtotal assets related to Other Services and Production and Commercialization of Liquids		133,398,529		-		(1,863,128	)		10,430,774			141,966,175		54,298,722		(1,863,128	)		4,737,367				57,172,961		84,793,214
Lands		1,417,568		-		-			-			1,417,568		-		-			-		-		-		1,417,568
Buildings and constructions		15,604,574		-		-			372,507			15,977,081		7,887,429		-			308,816		2.0		8,196,245		7,780,836
Facilities and features in building		1,157,039		-		-			20,995			1,178,034		526,674		-			35,163		4.0		561,837		616,197
Machinery, equipment and tools		5,353,477		237,299		-			28,117			5,618,893		3,461,019		-			554,096	6.7 to 10			4,015,115		1,603,778
UT Machinery, equipment and tools		3,641		-		-			-			3,641		3,641		-			-	6.7 to 10			3,641		-
Computers and Telecommunication systems		22,870,210		-		-			1,458,548			24,328,758		17,579,964		-			1,577,198	6.7 to 20			19,157,162		5,171,596
Vehicles		2,221,358		159,632		-			-			2,380,990		1,721,854		-			182,037		20		1,903,891		477,099
Furniture		955,440		7,472		-			41			962,953		902,025		-			9,219		10		911,244		51,709
Materials		15,791,047		6,275,734		(96,242	)		(5,242,745	)		16,727,794		-		-			-		-		-		16,727,794
Line pack		2,133,003		-		-			-			2,133,003		110,662		-			-		-		110,662		2,022,341
Works in progress		19,226,284		14,933,727		-			(16,151,445	)		18,008,566		-		-			-		-		-		18,008,566
Total		613,612,215		21,613,864		(1,959,370	)		-			633,266,709		321,077,572		(1,863,128	)		19,572,669				338,787,113		294,479,596

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

	2021
	Cost												Depreciation and Impairment
													Accumulated at									Accumulated at
	Beginning										End of the		the beginning									the end		Net
Account	of the year		Additions		Retirements			Transfers			year		of the year		Retirements			For the year		rate %		of the year		book value
Pipelines		263,565,765		-		(586	)		1,501,452			265,066,631		138,428,020		(341	)		6,427,820		2.2		144,855,499		120,211,132
Compressor plants		112,497,073		-		(74	)		4,343,362			116,840,361		75,761,325		(70	)		4,891,337		3.3 a 25		80,652,592		36,187,769
Other plants		106,030		-		-			-			106,030		42,726		-			3,387		3.3		46,113		59,917
Stations of regulation and/or measurement of pressure		8,933,021		-		-			569,556			9,502,577		7,240,802		-			248,260		4.0		7,489,062		2,013,515
Other technical installations		1,701,491		-		-			262,955			1,964,446		1,499,144		-			43,172		6.7		1,542,316		422,130
Subtotal assets related to natural gas transportation service		386,803,380		-		(660	)		6,677,325			393,480,045		222,972,017		(411	)		11,613,976				234,585,582		158,894,463
Non-regulated segment Pipelines		43,383,354		-		-			136,823			43,520,177		1,942,152		-			1,441,686		2.2		3,383,838		40,136,339
Non-regulated segment Compressor plants		8,361,565		-		-			60,442			8,422,007		4,093,187		-			876,704		3.3 a 25		4,969,891		3,452,116
Non-regulated segment Other plants		75,790,110		-		-			1,796,196			77,586,306		43,017,260		-			1,965,395		3.3		44,982,655		32,603,651
Non-regulated segment Stations of regulation and/or measurement of pressure		2,616,454		2,643		-			210,051			2,829,148		275,237		-			109,275		4.0		384,512		2,444,636
Non-regulated segment Other technical installations		1,016,791		-		-			24,100			1,040,891		485,393		-			92,433		6.7		577,826		463,065
Subtotal assets related to Other Services and Production and Commercialization of Liquids		131,168,274		2,643		-			2,227,612			133,398,529		49,813,229		-			4,485,493				54,298,722		79,099,807
Lands		1,417,568		-		-			-			1,417,568		-		-			-		-		-		1,417,568
Buildings and constructions		14,995,664		-		(12	)		608,922			15,604,574		7,588,478		(10	)		298,961		2.0		7,887,429		7,717,145
Facilities and features in building		1,055,941		-		(39	)		101,137			1,157,039		495,969		(37	)		30,742		4.0		526,674		630,365
Machinery, equipment and tools		4,687,684		425,882		-			239,911			5,353,477		2,999,073		-			461,946		6.7 a 10		3,461,019		1,892,458
UT Machinery, equipment and tools		3,641		-		-			-			3,641		3,641		-			-		6.7 a 10		3,641		-
Computers and Telecommunication systems		21,180,182		-		-			1,690,028			22,870,210		15,932,596		-			1,647,368		6.7 a 20		17,579,964		5,290,246
Vehicles		2,070,127		153,637		(2,406	)		-			2,221,358		1,547,470		(2,001	)		176,385		20.0		1,721,854		499,504
Furniture		918,308		37,054		-			78			955,440		895,747		-			6,278		10.0		902,025		53,415
Materials		13,940,845		6,478,730		(125,178	)		(4,503,350	)		15,791,047		-		-			-		-		-		15,791,047
Line pack		2,133,003		-		-			-			2,133,003		110,662		-			-		-		110,662		2,022,341
Works in progress		12,695,872		13,572,075		-			(7,041,663	)		19,226,284		-		-			-		-		-		19,226,284
Total		593,070,489		20,670,021		(128,295	)		-			613,612,215		302,358,882		(2,459	)		18,721,149				321,077,572		292,534,643

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The following is the composition of the resulting net book value of Property, plant and equipment as of December 31, 2022 and 2021:

	2022			2021
Cost		633,266,709			613,612,215
Accumulated depreciaton		(338,787,113	)		(321,077,572	)
Total		294,479,596			292,534,643

As of December 31, 2022 and 2021, the assets related to the Other Services and Production and Commercialization of Liquids segments contains the following assets for right of use:

	2022		2021
Other plants		986,979		1,256,155
Compressor plants		2,450,404		3,118,695
Other technical installations		278,631		354,621
Total		3,716,014		4,729,471

The book value variation of the rights-of use accounted during the years ended on December 31, 2022 and 2021 corresponds to its depreciation:

	2022			2021
Other plants		(269,176	)		(269,177	)
Compressor plants		(668,291	)		(668,293	)
Other technical installations		(75,990	)		(75,989	)
Total		(1,013,457	)		(1,013,459	)

The right to use these assets expires in September 2026, at which time the purchase options provided for in the contracts may be exercised.

13. LOANS

Short-term and long-term loans as of December 31, 2022 and 2021 comprise the following:

	2022		2021
Current Loans
2018 Notes Interest		937,379		1,075,060
Bank loans		1,440,989		-
Other financial liabilities		377,415		-
Leasing (Note 21)		1,164,146		1,224,678
Total Current loans		3,919,929		2,299,738
Non Current Loans
2018 Notes		83,292,496		95,458,303
Leasing (Note 21)		3,098,069		4,662,971
Bank loans		4,303,571		-
Total non current loans		90,694,136		100,121,274
Total (1)		94,614,065		102,421,012

⁽¹⁾ As of December 31, 2022 and 2021, it is net of Notes repurchase of Ps 5,257,400 and Ps. 4,484,852, respectively.

⁽²⁾ Net of issuance expenses of Ps. 30,105 and Ps. 102,623 as of December 31, 2022 and 2021, respectively.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Loans are totally denominated in US dollars.

The activity of the loans as of December 31, 2022 and 2021 is the following:

	2022						2021
	Leases liabilities			Other payables			Leases liabilities			Other payables
Beginning balance		5,887,649			96,533,363			8,505,178			120,481,460
Inflation adjustment restatement		(4,769,942	)		(58,645,278	)		(3,164,211	)		(44,998,198	)
Accrued interest		382,649			5,875,804			568,315			7,321,812
Effect of foreign exchange effect		4,005,769			47,656,779			1,730,223			22,095,210
VAT unpaid installments		23,182			-			26,212			-
Proceeds from loans		-			6,164,853			-			-
Acquisition of notes result		-			1,030,169			-			806,841
Payment of loans(1)		(901,526	)		(86,187	)		(1,163,922	)		-
Acquisition of notes		-			(2,452,516	)		-			(1,869,224	)
Interest paid(2)		(365,566	)		(5,725,137	)		(614,146	)		(7,304,538	)
Ending balance		4,262,215			90,351,850			5,887,649			96,533,363

⁽¹⁾ For the years ended on December 31, 2022 and 2021, Ps. 901,526 and Ps. 1,163,922 respectively were cancelled through the offseting of debit balances maintained with the creditor (Pampa Energía).

⁽²⁾ For the years ended on December 31, 2022 and 2021, Ps. 365,566 and Ps. 614,146, respectively, were cancelled through the offseting of debit balances maintained with the creditor (Pampa Energía).

The maturities of the current and non-current loans as of December 31, 2022 are as follows, not including issuance expenses:

			To due
	Due at 12/31/2022		From 1/01/2023 to 12/31/2023		From 1/01/2024 to 12/31/2024		From 1/01/2025 to 12/31/2025		From 1/01/2026 to 12/31/2026		From 1/01/2027 onwards		Total
2018 Notes		-		937,379		-		83,292,496		-		-		84,229,875
Financial Leasing		133,549		1,030,597		1,117,025		1,210,816		770,228		-		4,262,215
Other financial liabilities		-		377,415		-		-		-		-		377,415
Bank loans		-		1,440,989		4,303,571		-		-		-		5,744,560
Total		133,549		3,786,380		5,420,596		84,503,312		770,228		-		94,614,065

The following table sets reconciliation between the total of future minimum lease payments as of December 31, 2022, and their present book value:

	12/31/2022
As of 12/31/2023		1,458,705
From 1/01/2024 to 12/31/2024		1,325,334
From 1/01/2025 to 12/31/2025		1,325,334
From 1/01/2026 to 12/31/2026		791,728
From 1/01/2027 onwards		-
Total minimum future payments		4,901,101
Future financial charges on financial leases		(638,886	)
Book Value financial leases		4,262,215

As of December 31, 2022 and 2021, the Company and its controlled companies are in compliance with the covenants established in all of their financial debt.

Description of the indebtedness of the Company

Class 2 Notes (“2018 Notes”)

The Ordinary General Shareholders’ Meeting held on April 26, 2017, ordered the increase of up to US$ 700,000,000 (or its equivalent in other currencies) of the 2017 Program authorized by the CNV by Resolution No. 17,262 dated January 3, 2014, whose amount until the Shareholders´ Meeting was held was US$ 400,000,000 (the “2017 Program”).

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

On May 2, 2018, within the framework of the 2017 Program, the Company issued the 2018 Notes according to the following characteristics:

	2018 Notes
Amount in U.S.$	500,000,000
Interest Rate	6.75% annual
Issuance price	99.725%

	Scheduled payment date	Percentage of the principal to be paid
Amortization	May 2, 2025	100%
Frequency of interest payment	Semiannual, payable on May 2 and November 2 of each year.
Guarantor	None

The authorization for the public offering of the 2017 Program was granted by the CNV through Resolutions No. 17,262 and 18,938 dated January 3, 2014 and September 15, 2017, respectively. On October 31, 2018, through Disposition No. DI-2018-55-APN-GE#CNV, the CNV granted the extension of the 2017 Program until January 3, 2024.

The Ordinary General Shareholders´ Meeting held on August 15, 2019 decided to increase the 2017 Program from US$ 700 million to US$ 1,200 million. This increase was authorized by the CNV on October 9, 2019 through Resolution RESFC-2019-20486-APN-DIR # CNV.

Funds obtained by the Company are applied to:

i. The repurchase of the Class 1 Notes (the “2014 Notes”) for U.S.$ 86,511,165;

ii. the cancellation and total redemption of the 2014 Notes for U.S.$ 120,786,581;

iii. the balance of net funds to make investments in capital expenditures.

The value of the financial debt is based on its amortised cost calculated as cash flows discounted at an effective rate of 7.088%.

During 2022 and 2021, the Company repurchased its marketable debt for a nominal value of USD 29.7 million and USD 4.8 million for which it paid Ps. 2,452,516 and Ps. 1,869,224, respectively. These transactions generated a result of (Ps. 1,030,169) and (Ps. 806,841) respectively, recognized in the financial results of the Statement of Income.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Other financial liabilities

As of December 31, 2022, Other financial liabilities includes:

Currency	Amount (in thousands)		Interest rate		Expiration date
USD		1,797		5.75% - 7.75%	Between May and September 2023
Euros		284		3.05% - 3.85%	April / May 2023
USD		8,000		4.30%	August 2023

Bank loans

On March 31, 2022, the subsidiary Telcosur, took a loan for US$24 million. The main terms of said loan are:

Amount in US$		24.000.000
Interest rate	1.5% annual
Amortizacion date	January 25, 2024
Interest payment frequency	To the expiration
Guarantee	Fixed term in foreign currency (1)

⁽¹⁾ Included as “Non-current financial assets measured at amortised cost”.

Covenants

As of December 31, 2022, the Company has complied with a series of restrictions derived from its current financial agreements, which include, among others, those related to obtaining new loans, payment of dividends, granting of guarantees, disposal of certain assets and make certain transactions with related parties.

he Company may contract new debts under the following conditions, among others:

a. To the extent that after the new debt has been incurred (i) the consolidated coverage ratio (calculated as the quotient of the consolidated adjusted EBITDA -earnings before financial results, income tax, depreciation and amortization- and the consolidated interest expense) is equal or higher than 2.0:1; and (ii) the consolidated debt ratio (calculated as the quotient of the consolidated debt and the consolidated EBITDA) is equal to or lower than 3.75:1.

b. For the refinancing of the outstanding financial debt.

c. Originated by customer advances.

The Company may pay dividends under the following conditions: (i) the Company is not in default under 2018 Notes, and (ii) immediately after any dividend payment, the Company may incur new debts according to the provisions in point a. of the preceding paragraph.

Lease liability

Corresponds to the financing obtained for the acquisition of the corresponding assets to the treatment and compression plant located in the area of Río Neuquén. Said agreement was concluded on August 11, 2016 with Petrobras (currently Pampa Energía) and consists of the payment of 119 consecutive monthly installments of U.S.$ 623,457 without taxes and an option to purchase for the same amount payable at the end of the 120th month of the effectiveness of the contract.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

14. INCOME TAX AND DEFERRED TAX

Tax Reform

The Tax Reform sanctioned in Argentina in 2017, with some amendments introduced in December 2018 after the issuance of Law No. 27,468, brought with it a series of modifications in the taxation and calculation of the income tax to which the Company is subject in the normal course of its activities. Subsequently, on the occasion of the enactment of the Solidarity Law, new modifications were introduced with impact as of the fiscal year beginning on January 1, 2019. The main changes are the following:

Applicable rate

Until the fiscal year ended on December 31, 2017, the income tax rate remained at 35%. The tax reform establishes a gradual reduction of the applicable rate for the calculation of income tax, being 30% and 25% for fiscal periods beginning on January 1, 2018 and 2019 and January 1, 2020 onwards, respectively.

The reduction in the applicable rate is complemented by the application of a tax on the distribution of dividends made to human persons and foreign beneficiaries, which the Company must withhold and enter the Tax authority as a single and definitive payment when the dividends are paid. This additional tax will be 7% or 13%, depending on whether the dividends distributed correspond to earnings of a fiscal period in which the Company was reached at the rate of 30% or 25%, respectively.

Solidarity Law suspended until fiscal years starting from 1st January 2021 inclusive, reduced to 25% of the applicable rate and retention of 13% on dividends.

On June 16, 2021, “Law No. 27,630: Amending the Income Tax Law” was published in the Official Gazette, which, among other issues, introduces a modification in the income tax rate effective for the years fiscal or fiscal years beginning on or after January 1, 2021 inclusive. The amendment establishes a tiered system of rates in three segments ( 25%, 30% and 35%) according to the level of accumulated net taxable income, which will be updated.

Likewise, dividends distributed to foreign individuals and beneficiaries will be taxed at a rate of 7%.

For the determination of the deferred and current income tax charge as of December 31, 2022 and 2021, the Company has applied the current progressive tax rate according to the scale updated by AFIP Resolution No. 5168/2022 of March 15, 2022.

Tax adjustment for inflation

Law No. 27,468 establishes that in the net taxable income of the periods beginning on or after January 1, 2018, the adjustment for inflation obtained by the application of the income tax law may be deducted or incorporated into the tax result for the fiscal year. This adjustment will proceed only if the percentage variation in the IPC, will accumulate (a) a percentage higher than 100% in the 36 months prior to the end of the year, or (b) regarding the first, second and third fiscal year that starts from its effective date, an accumulated variation of the IPC that exceeds 55%, 30% or 15% of said 100%, respectively.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

For the fiscal year ended December 31, 2022 and 2021, the CPI has exceeded the 100% threshold mentioned above, so the Company has measured the tax charge to earnings for the year ended December 31, 2022 and 2021 considering the application of the adjustment for fiscal inflation.

According to the Solidarity Law, the positive or negative result generated by the application of the inflation adjustment corresponding to the first and second fiscal year beginning on January 1, 2019 will be charged in a sixth in that fiscal period and the five sixths remaining in equal parts in the following 5 fiscal periods. As of January 1, 2021, 100% of the adjustment may be deducted/taxed in the year in which the effect is determined.

Adjustment of acquisitions and investments made in fiscal years beginning on or after January 1, 2018

A cost adjustment mechanism is established for assets acquired or investments made in fiscal years beginning on or after January 1, 2018. The adjustment will be made based on the percentage variations of the IPIM.

Tax revaluation

It established the possibility of carrying out a tax revaluation, for a single time, of certain assets that are part of the assets as of December 31, 2017, in order to adjust their value.

The taxpayers that exercised the revaluation option waived to promote any judicial or administrative process for which the adjustment for tax inflation is claimed.

The Board of Directors decided to make use of this option.

On August 16, 2022, RG No. 5268/2022 was published through which the AFIP ordered an extraordinary advance of income tax. The extraordinary advance payment constitutes an additional payment on account to that provided for in the general advance payment regime that can be added to the latter. For fiscal year 2022, the Company paid the AFIP Ps. 3,367,653 for this concept.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Deferred Tax

The reconciliation between the charge computed for tax purposes and the income tax expense charged to the statement of comprehensive income in the years ended December 31, 2022, 2021 and 2020 is as follows:

	2022			2021			2020
Current income tax		(15,857,624	)		(26,694,111	)		(10,113,083	)
Deferred income tax		(1,203,529	)		1,883,262			(2,836,978	)
Total income tax		(17,061,153	)		(24,810,849	)		(12,950,061	)

The analysis of the net deferred tax assets and liabilities is as follows:

	2022			2021
Deferred tax assets:
Deferred tax assets to be recovered after more than 12 months		3,626,709			7,846,119
Deferred tax assets to be recovered after less than 12 months		1,412,828			1,247,816
Deferred tax liabilities:
Deferred tax liabilities taxable after more than 12 months		(25,574,208	)		(28,787,450	)
Deferred tax liabilities taxable after less than 12 months		(686,246	)		(323,873	)
Deferred tax liabilities, net		(21,220,917	)		(20,017,388	)

The components of the net deferred tax assets and liabilities as of December 31, 2022, 2021 and 2020 are the following:

Deferred tax assets	Other receivables			Account receivables discounted value			Provisions for legal claims and other provisions			Financial leases			Contract liabilities		Tax loss carryforward			Tax inflation adjustment			Financial assets at fair value through profit or loss		Total
As of December 31, 2020		39,744			1,891			656,071			2,140,878			1,880,469		2,776			49,211			-		4,771,040
Charge in results		(39,744	)		(115	)		351,911			(133,032	)		869,196		3,294,662			(19,983	)		-		4,322,895
As of December 31, 2021		-			1,776			1,007,982			2,007,846			2,749,665		3,297,438			29,228			-		9,093,935
Charge in results		-			(1,776	)		(366,049	)		(562,847	)		6,764		(3,297,438	)		(16,667	)		183,615		(4,054,398	)
As of December 31, 2022		-			-			641,933			1,444,999			2,756,429		-			12,561			183,615		5,039,537

Deferred tax liabilities	Other receivables			Loans			Property, Plant and Equipment			Cash and cash equivalents			Inventories			Financial assets at amortized cost			Tax inflation adjustment			Other liabilities			Total
As of December 31, 2020		-			(58,641	)		(15,369,172	)		(3,047	)		(98,569	)		(592,588	)		(10,549,673	)		-			(26,671,690	)
Charge in results		(5,226	)		(104,771	)		(6,035,973	)		(30,571	)		(28,274	)		592,588			3,424,894			(252,300	)		(2,439,633	)
As of December 31, 2021		(5,226	)		(163,412	)		(21,405,145	)		(33,618	)		(126,843	)		-			(7,124,779	)		(252,300	)		(29,111,323	)
Charge in results		(114,164	)		23,424			(1,417,423	)		(392,781	)		6,984			-			4,492,529			252,300			2,850,869
As of December 31, 2022		(119,390	)		(139,988	)		(22,822,568	)		(426,399	)		(119,859	)		-			(2,632,250	)		-			(26,260,454	)

As of December 31, 2021, the Company had a specific tax carryforward derived from negative exchange differences for the years 2021 and 2020 generated by financial instruments traded abroad for Ps. 3,662,207. The realization of such tax loss depended on the future generation of taxable financial gains taxed during the statute of limitations period. In order to determine its recoverability, the Company took into consideration the reversal of the deferred items, its tax planning and projections of future specific taxable income based on its best estimate. Based on these projections and because it was not possible to estimate as probable the generation of future specific financial gains to absorb such tax loss, no deferred tax asset of Ps. 364,769 was recognized as of December 31, 2021. During the year ended on December 31, 2022, the tax loss carryforward was totally recovered.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Income tax expense computed at the statutory tax rate on pre-tax income differs from the income tax expense for the years ended December 31, 2022, 2021 and 2020 as follows:

	2022			2021			2020
Pre tax income		49,378,955			65,583,161			22,612,275
Statutory income tax rate		35	%		35	%		30	%
Pre tax income at statutory income tax rate		(17,282,634	)		(22,954,106	)		(6,783,682	)
Tax effects due to:
- Restatement by inflation		2,968,108			11,276,529			6,159,982
- Tax loss variation		-			3,297,438			-
- Unrecognized tax loss carryforward		-			-			(5,988,032	)
- Adjustment affidavit previous year		(82,082	)		(131,655	)		(26,677	)
- Tax inflation adjustment		(2,717,831	)		(7,678,237	)		(8,159,343	)
- Variation of tax rate		-			(7,955,019	)		-
- Others		53,286			(665,799	)		1,847,691
Total income tax		(17,061,153	)		(24,810,849	)		(12,950,061	)

15. PROVISIONS

The total amount of the Provisions is included in current liabilities.

	For legal claims and others
Balances as of 12/31/2020		2,530,671
Inflation adjustment restatement		(1,023,648	)
Additions		1,036,496		(1)
Uses		(9,751	)
Decreases		(9,535	)	(3)
Balances as of 12/31/2021		2,524,233
Inflation adjustment restatement		(1,445,722	)
Additions		804,831		(2)
Uses		(20,248	)
Decreases		(29,000	)	(3)
Balances as of 12/31/2022		1,834,094

⁽¹⁾ Ps. 557,718 are included in “Other operating expenses” and Ps. 478,778 in “Financial expenses”.

⁽²⁾ Ps. 356,890 are included in “Other operating expenses” and Ps. 447,941 in “Financial expenses”.

⁽³⁾ The total are included in “Other operating expenses”.

16. FINANCIAL RISK MANAGEMENT

16.1 Financial risk factors

The Company’s activities and the market in which it operates expose it to a series of financial risks: market risk (including foreign exchange risk, interest rate risk, and commodity price risk), credit risk and liquidity risk.

The Company’s risk management framework establishes that a risk map is determined that measures the potential impact of each of them on the financial situation and results of operations. Based on this, the Executive Officers are responsible for defining the policies, procedures, limits and measures aimed at mitigating the impact of said risks.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The sensitivity analyzes included below are based on the change in one of the factors while all others remain constant. In practice, this is unlikely to happen, and changes in several factors can be correlated, for example, in variations in the interest rate and variations in the foreign currency exchange rate.

Sensitivity analysis only provides limited vision, at one point in time. The actual impact on the Company’s financial instruments could vary significantly with respect to the impact shown in the sensitivity analysis.

16.1.1 Risk associated with exchange rates

Restrictions to the single free market for foreign exchange (“MULC”)

As mentioned in Note 1, the main global and Argentine economic variables have had a negative impact on financial markets affecting the cost of borrowing, hedging activities, liquidity and access to capital in general. In the local market, particularly, the shares of the main listed companies, sovereign bonds and the Argentine peso experienced a sharp drop in value.

Additionally, as from April 2020, through the issuance of Communication “A” 7001, subsequently amended by Communications “A” 7030, 7042, 7052, 7068 and 7138, the BCRA established measures that intensify the restrictions for access to the MULC, including measures related to the trading of stock market assets by companies.

In turn, on May 25, 2020 and June 19, 2020, the CNV issued General Resolutions No. 841 and 843, by means of which restrictions are established for the purchase and sale of negotiable securities in U.S. dollars, or the transfer of such securities to depositary companies abroad. Subsequently, by means of General Resolution No. 862, such agency provided certain flexibilities to the terms of permanence of such securities.

These measures aimed at restricting the MULC in order to contain the demand for dollars imply the request of prior authorization from the BCRA for certain transactions, including the following:

- Payment of dividends to non-residents;

- Payment of imports of certain goods abroad or cancellation of debts originated in the importation of such goods except for certain exceptions expressly provided for in the applicable regulations;

- The formation of foreign assets; and

- Payment of financial loans to non-residents.

In case of having requested access to the MULC, it must assume the commitment to enter and settle in the foreign exchange market, within five working days of its availability, those funds received abroad originated in the collection of loans granted to third parties, the collection of a time deposit or the sale of any type of asset, when the asset had been acquired, the deposit constituted or the loan granted after May 28, 2020.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Additionally, on September 15, 2020, the BCRA published Communications “A” 7105 and 7106 by which it is established, among other measures, that those who register financial debts with independent parties with principal maturities in foreign currency scheduled between October 15, 2020 and March 31, 2021, must submit to the BCRA a refinancing plan for the principal maturities based on the following criteria: (a) that the net amount for which the exchange market will be accessed in the original terms will not exceed 40% of the principal amount maturing in the period indicated above, and (b) that the remaining principal be, at least, refinanced with new external indebtedness with an average life of 2 years, provided that the new indebtedness is settled in the exchange market.

During 2022, although various regulations have been issued that, to a greater or lesser extent, provided for certain flexibility in access to the MULC, the BCRA continued to limit access to them in order to preserve its reserves and stabilize its exchange rate policy.

The aforementioned rule does not have immediate effect on the Company since the amortization of the principal of its marketable debentures occurs on May 2, 2025, which is not within the aforementioned term. On the other hand, as of the date of issuance of these consolidated financial statements, the Company paid all the interest installment corresponding to its financial debt on November 2, 2020.

Additionally, the exchange regime already determined as mandatory the entry and liquidation in local currency of the funds obtained as a result of the following operations and concepts, among others:

- Exports of goods and services;

- Collection of pre-financing, advances and post-financing of exports of goods;

- Exports of services;

- Disposal of foreign assets.

These foreign exchange restrictions, or those that may be enacted in the future, could affect the Company’s ability to access the official foreign exchange market to acquire the foreign currency necessary to meet its financial obligations. Assets and liabilities denominated in foreign currency as of December 31, 2021 have been valued considering the current exchange rates in the MULC.

Exchange rate risk management

In view of the main impacts of the aforementioned situation and those detailed in Note 1 to these Consolidated Financial Statements, the Company has implemented a series of measures to mitigate their impact. In this sense, the Company’s Management permanently monitors the evolution of the situations that affect its business, in order to determine the possible actions to be taken and identify the eventual impacts on its equity and financial situation. The Company considers that its current financial position will allow it to comply, in the short term, with its foreign currency commitments. The Company’s financial statements should be read in light of these circumstances.

The Company is primarily exposed to the fluctuation of the exchange rate of the U.S. dollar against the Argentine Peso due to the fact that almost its entire financial indebtedness is denominated in U.S. dollars. The exposure to other currencies is not significant.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

As regards to the revenue derived from the Natural Gas Transportation segment, the tariffs charged by the Company are currently denominated in Argentine pesos. On the other hand, revenues in US dollars derived from the Liquids Production and Commercialization segment accounted for approximately 87% of the segment’s total revenues for the years ended December 31, 2022, 2021 and 2020. Total operating cost denominated in Argentine Pesos accounted for 83%, 81% and 80% for the years ended December 31, 2022, 2021 and 2020, respectively.

As of December 31, 2022, 2021 and 2020, 35%, 37% and 50% of total revenues are denominated in Argentine pesos, respectively.

tgs’ financial risk management policies are defined with the objective of mitigating the impact of exchange rate fluctuations on the Company’s foreign currency position. To this end, alternative investment evaluations are regularly carried out to diversify tgs’ investment portfolio among instruments denominated in U.S. dollars or, although denominated in Argentine pesos, to obtain positive returns in real terms.

Additionally, if deemed appropriate, the Company enters into derivative financial instruments that allow hedging the fluctuation of the U.S. dollar on the positions in such currency in the long term. During fiscals years 2020 and 2019, the Company did not contract derivative financial instruments to hedge this risk.

However, the Company, in order to mitigate the impact on the future variation of the exchange rate, has placed funds in assets denominated in U.S. dollars. As of December 31, 2022, 89% of the Company’s fund placements are denominated in U.S. dollars.

For further information regarding the Company’s foreign currency position see “Note 18. Foreign currency assets and liabilities”.

Management of the Company estimates that, based on the net liability position as of December 31, 2022 and 2021, a 10% appreciation in the exchange rate of the U.S. dollar against the Argentine peso, with all other economic-financial variables stable, could have resulted in a pre-tax loss of Ps. 1,975,626 and Ps. 3,962,154, respectively. A 10% depreciation of the U.S. dollar against the Argentine peso would have an equal and opposite effect on the Statement of Comprehensive Income. This sensitivity analysis is theoretical as the actual impacts could differ significantly and vary over time.

In order to mitigate the exchange rate risk, during fiscal year 2022, tgs entered into both forward purchase operations of US dollars, as well as investments in mutual funds linked to the US dollar in order to hedge exposure to the risk associated with the exchange rate that derives from its financial debt.

16.1.2 Interest rate risk

Interest rate risk management seeks to reduce financial costs and limit the Company’s exposure to increases in interest rates. tgs’ exposure to risks associated with interest rate variations is limited given that all of its financial debt is subject to fixed interest rates. Information regarding the Company’s financing is disclosed in Note 13.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

In addition, the main objective of the Company’s financial investment activities is to obtain the highest return by investing in low-risk and highly liquid instruments. The Company maintains a portfolio of cash equivalents and short-term investments comprised of investments in mutual funds and deposits in interest-bearing bank accounts, public and private securities. The risk of these instruments is low since they are mostly short-term and highly liquid in recognized financial institutions.

As a consequence of the application of IAS 29, maintaining monetary assets generates loss of purchasing power, provided that such items are not subject to an adjustment mechanism that compensates to some extent the loss of purchasing power. This loss of purchasing power is included in the result of the period under gain on the net monetary position. On the contrary, maintaining monetary liabilities generates a gain in purchasing power, which are also included in such line item.

The Company’s risk management policies are defined with the objective of reducing the impact of the loss of purchasing power. During the 2022, 2021 and 2020 fiscal years the Company has maintained a liability monetary position. As a consequence, tgs has recorded a net gain from exposure to inflation in the monetary items.

The following table shows a breakdown of the Company’s fixed-rate and floating-rate financial assets and liabilities as of December 31, 2022 and 2021:

	Financial assets				Financial liabilities (1)
	2022		2021		2022		2021
Fix interest rate		39,323,688		43,932,998		86,048,279		96,533,363
Variable interest rate		2,665,814		34,048,991		-		-
Total		41,989,502		77,981,989		86,048,279		96,533,363

⁽¹⁾ Includes 2018 Notes. For further information see Note 13 to the Consolidated Financial Statements.

In view of the nature of the Company’s financial assets which bear variable interest, an immediate 100 basis points decrease in the interest rate would not have a significant impact on the total value of the financial assets.

16.1.3 Commodity price risk

Commercial operations performed by the Company in its Liquids Production and Marketing segment are affected by a number of factors beyond its control, including changes in the international prices of the products sold, and government regulations on prices, taxes and other charges, among others.

The sales prices of exported propane, butane and natural gasoline are determined according to international reference prices (Mont Belvieu for propane and butane and NWE ARA for natural gasoline). Additionally, most of the total sales of propane and butane that are made in the domestic market are made at prices set by the Ministry of Energy for the different market segments.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

These prices have historically fluctuated in response to macroeconomic conditions and changes in supply and demand, which could affect tgs’ profitability. Especially during the first half of 2020, and due to the effect of COVID and the international oil market situation, the price of Liquids was negatively affected with year-on-year declines during that period in the order of 30%. However, as of the last quarter of 2020 and after the end of the year, international prices recovered sharply.

Based on volume of sales for the years ended December 31, 2022, 2021 and 2020, tgs estimated that, other factors being constant, a decrease of US$ 50 per ton in the international price of LPG and natural gasoline, respectively, would have decrease the Company’s net comprehensive income in its Liquids Production and Commercialization segment in Ps. 3,207,213, Ps. 4,378,871 and Ps. 5,935,956, respectively. On the other hand, an increase of US$ 50 per ton in the international price would have had the opposite effect.

16.1.4 Credit risk

The Company’s exposures to credit risk takes the form of a loss that would be recognized if counterparties failed to, or were unable to, meet their payment obligations. These risks may arise in certain agreements in relation to amounts owed for physical product sales, the use of derivative instruments, and the investment of surplus cash balances. This risk mainly results from economic and financial factors or from a possible default of counterparty.

The Company is subject to credit risk arising from outstanding receivables, cash and cash equivalents and deposits with banks and financial institutions, and from the use of derivative financial instruments. The Company’s policy is to manage credit exposure to trading counterparties within defined trading limits.

To measure the expected credit loss, receivables from sales have been grouped according to their characteristics in terms of credit risk and the time that has elapsed since maturity.

On this basis, the provision for losses for the year ended December 31, 2022 for trade receivables was determined as follows:

Ratio	Non-due			90 days			120 days			180 days			+240 days
Natural Gas Transportation segment		0	%		0.50	%		5	%		10	%		100	%
Other segments		0	%		0.25	%		2	%		5	%		100	%

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Trade and other receivables

If any of the Company’s customers are independently rated, these ratings are used. Otherwise, if there is no independent rating, the Company assesses the credit quality of the customer taking into account its financial position, past experience and other factors. The Company may seek cash collateral, letter of credit or parent company guarantees, as considered appropriate.

As of December 31, 2022 and 2021, current and non-current sales receivables, net of allowance for doubtful accounts, amounted to:

	2022			2021
Current trade receivables		17,071,816			20,951,996
Allowances for doubful accounts (1)		(132,521	)		(258,142	)
Total		16,939,295			20,693,854

⁽¹⁾
Said amount represents the best estimate made by tgs according to what is stated in Note 4.b).

       Likewise, as of December 31, 2022 and 2021, the Company has credits for subsidies with the Argentine government for Ps. 3,768,159 and Ps. 2,427,450, respectively.

In the ordinary course of business, the Company provides natural gas transportation services mainly to natural gas distribution companies, CAMMESA and Pampa Energía. The amounts of net sales made to the principal customers to which Natural Gas Transportation services were provided in the years ended December 31,2022, 2021 and 2020 and the sales receivable balances (net of allowances) as of December 31, 2022 and 2021 are set forth below:

	2022				2021				2020
	Revenues		Trade receivables		Revenues		Trade receivables		Revenues
MetroGas		10,355,756		768,193		11,821,815		2,809,625		17,330,099
Camuzzi Gas Pampeana S.A.		7,668,510		567,671		8,708,964		681,780		12,813,975
Naturgy Argentina		6,286,027		483,552		7,051,418		586,216		10,358,472
CAMMESA		3,795,168		1,380,126		5,400,240		1,194,018		6,887,604
Pampa Energía		1,471,413		111,450		1,666,555		637,807		2,473,548
Camuzzi Gas del Sur S.A.		1,816,770		118,208		2,012,977		294,958		3,066,612

The amounts of Liquids Production and Marketing net sales made to major customers during the years ended December 31, 2022, 2021 and 2020 and sales receivable balances (net of allowances) as of December 31, 2022 and 2021 are set forth below:

	2022				2021				2020
	Revenues		Trade receivables		Revenues		Trade receivables		Revenues
PBB Polisur		25,589,826		3,569,289		26,657,675		2,778,544		27,355,042
Petredec		-		-		-		-		2,032,373
Geogas Trading S.A.		3,668,557		-		7,402,250		5,235,421		845,467
Italgas S.A.		-		-		295,028		-		1,165,237
YPF		2,598,667		160,887		3,700,237		66,832		2,862,061
Petrobras Global Trading BV		280,416		-		10,953,530		-		13,263,199
Trafigura Beheer		15,968,772		898,027		13,490,509		1,347,151		-
Pampa Energía		3,583,230		281,774		4,996,215		659,046		-

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The amounts of Other Services net sales made to major customers during the years ended December 31, 2022, 2021 and 2020 and sales receivable balances (net of allowances) as of December 31, 2022 and 2021 are set forth below:

	2022				2021				2020
	Revenues		Trade receivables		Revenues		Trade receivables		Revenues
Tecpetrol		2,270,548		417,806		875,955		87,291		176,811
Exxonmobil Exploration		1,633,267		242,524		1,854,769		243,569		1,682,932
YPF		4,278,334		845,134		4,530,193		893,039		3,954,508
Vista Oil		235,425		121,741		-		26,881		-
Pluspetrol		2,638,534		275,192		2,352,809		535,042		1,730,764
Pampa Energía		3,972,826		906,281		2,365,465		523,735		1,792,010

Cash and financial placements

The credit risk on cash and cash equivalents and other financial placements is limited since tgs has short-term fund placement policies whose main objective is to obtain an adequate return based on market characteristics and minimizing risk exposure. These placements are diversified in different financial institutions with adequate credit ratings in order to limit exposure to a few financial institutions. The Company’s maximum exposure to credit risk will be given by the carrying value of assets included in cash and cash equivalents and other financial assets at amortised cost.

During the years 2022, 2021 and 2020 the Company has carried out transactions with financial instruments traded abroad, mainly national and provincial government bonds, which resulted in exchange losses of Ps. 1,613,742, Ps. 3,694,962 and Ps. 23,456,438, respectively, which are recorded as “Other financial results - Result from valuation at fair value of financial assets through profit or loss” in the Statement of comprehensive income for the year ended December 31, 2022, 2021 and 2020.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Below is a detail of the maturities of the financial assets included in (i) cash and cash equivalents, (ii) other financial assets, (iii) trade receivables and  (iv) other receivables as of December 31, 2022 and 2021:

December 31, 2022
	Cash and cash equivalents		Other financial assets		Credits (1) (2)
Without specified maturity		2,988,946		39,289,630		40,389
With specified maturity
Overdue
Until 12-31-2021		-		-		173,477
From 01-01-22 to 03-31-22		-		-		8,167
From 04-01-22 to 06-30-22		-		-		26,427
From 07-01-22 to 09-30-22		-		-		22,530
From 10-01-22 to 12-31-22		-		-		1,449,545
Total overdue		-		-		1,680,146
Non-due
From 01-01-23 to 03-31-23		-		192		19,536,293
From 04-01-23 to 06-30-23		-		192		113,994
From 07-01-23 to 09-30-23		-		1,054		57,932
From 10-01-23 to 12-31-23		-		-		3,753
During 2024		-		40,162,283		14,026
During 2025		-		-		-
During 2026		-		-		-
From 2027 onwards		-		-		-
Total non-due		-		40,163,721		19,725,998
Total with specified maturity		-		40,163,721		21,406,144
Total		2,988,946		79,453,351		21,446,533

⁽¹⁾ The total amount of the receivables without specified maturity is recorded in Non-current assets.

⁽²⁾ Includes financial assets recorded in trade receivables and other receivables, excluding allowance for doubtful accounts.

December 31, 2021
	Cash and cash equivalents		Other financial assets		Credits (1) (2)
Without specified maturity		8,627,004		24,456,434		73,421
With specified maturity
Overdue
Until 12-31-2020		-		-		264,751
From 01-01-21 to 03-31-21		-		-		-
From 04-01-21 to 06-30-21		-		-		-
From 07-01-21 to 09-30-21		-		-		81,875
From 10-01-21 to 12-31-21		-		-		3,376,015
Total overdue		-		-		3,722,641
Non-due
From 01-01-22 to 03-31-22		-		1,350		19,607,691
From 04-01-22 to 06-30-22		-		1,143		587,968
From 07-01-22 to 09-30-22		-		732		112,848
From 10-01-22 to 12-31-22		-		497		939
During 2023		-		45,108,956		14,377
During 2024		-		-		-
During 2025		-		-		-
From 2026 onwards		-		-		-
Total non-due		-		45,112,678		20,323,823
Total with specified maturity		-		45,112,678		24,046,464
Total		8,627,004		69,569,112		24,119,885

⁽¹⁾ The total amount of the receivables without specified maturity is recorded in Non-current assets.

⁽²⁾ Includes financial assets recorded in trade receivables and other receivables, excluding allowance for doubtful accounts.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

16.1.5 Liquidity risk

This risk involves the difficulties that tgs may have in meeting its commercial and financial obligations. To this end, the expected cash flow is regularly monitored.

tgs has policies for borrowing funds whose main objective is to cover financing needs at the lowest cost according to market conditions. One of the Company’s main objectives is to have financial solvency. Given the current conditions of the financial market, the Company believes that the availability of resources and the positive cash flow from operations are sufficient to meet its current obligations, despite having credit lines for borrowing funds.

Additionally, a methodology is used for the analysis and assignment of credit limits to the different financial entities in order to minimize the associated liquidity risk. In line with this, the Company invests its liquid funds in financial entities with an adequate credit rating.

Below is a detail of the maturities of the Company’s financial liabilities corresponding to: commercial debts, remunerations, other debts and financial debts as of December 31, 2022 and 2021. The amounts presented in the tables represent contractual undiscounted cash flows and, therefore, do not correspond to the amounts presented in the statement of financial position. These estimates are made on the basis of information available at the end of each year and may not reflect actual amounts in the future. Therefore, the amounts shown are provided for illustrative purposes only:

December 31, 2022
	Loans		Other financial liabilities		Leases liabilities
Without specified maturity		-		-		-
With specified maturity
Overdue
Until 12-31-2021		-		230,673		-
From 01-01-22 to 03-31-22		-		311		-
From 04-01-22 to 06-30-22		-		311		-
From 07-01-22 to 09-30-22		-		311		-
From 10-01-22 to 12-31-22		-		311		133,549
Total overdue		-		231,917		133,549
Non-due
From 01-01-23 to 03-31-23		-		12,547,599		331,289
From 04-01-23 to 06-30-23		3,316,733		78,747		331,289
From 07-01-23 to 09-30-23		1,541,798		-		331,289
From 10-01-23 to 12-31-23		2,989,575		-		331,289
During 2024		5,979,150		-		1,325,334
During 2025		91,569,575		-		1,325,334
During 2026		-		-		791,728
From 2027 onwards		-		-		-
Total non-due		105,396,831		12,626,346		4,767,552
Total with specified maturity		105,396,831		12,858,263		4,901,101
Total		105,396,831		12,858,263		4,901,101

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

December 31, 2021
	Loans		Other financial liabilities		Financial leases
Without specified maturity		-		-		-
With specified maturity
Overdue
Until 12-31-2020		-		576,851		-
From 01-01-21 to 03-31-21		-		606		-
From 04-01-21 to 06-30-21		-		606		-
From 07-01-21 to 09-30-21		-		606		-
From 10-01-21 to 12-31-21		-		606		150,834
Total overdue		-		579,275		150,834
Non-due
From 01-01-22 to 03-31-22		82,329		14,066,957		374,170
From 04-01-22 to 06-30-22		3,376,545		82,164		374,170
From 07-01-22 to 09-30-22		-		-		374,170
From 10-01-22 to 12-31-22		3,376,545		-		374,170
During 2023		6,753,090		-		1,496,884
During 2024		6,753,090		-		1,496,884
During 2025		103,422,323		-		1,496,884
From 2026 onwards		-		-		894,210
Total non-due		123,763,922		14,149,121		6,881,542
Total with specified maturity		123,763,922		14,728,396		7,032,376
Total		123,763,922		14,728,396		7,032,376

16.1.6 Capital management risk.

The Company’s objectives in managing capital are to safeguard the Company’s ability to continue as a going concern, to achieve an optimal cost of capital structure and to support the investment process in order to provide returns to shareholders and benefits to other stakeholders.

tgs seeks to maintain a level of cash generation from its operating activities that will enable it to meet all of its commitments.

The Company monitors capital on the basis of the leverage ratio. This ratio is calculated as total financial debt (including “current financial debt” and “non-current financial debt” as shown in the Statement of Financial Position) divided by total capital. Total capital is calculated as “Shareholders’ Equity”, as shown in the Statement of Changes in Shareholders’ Equity, plus total financial debt.

During the years ended December 31, 2022 and 2021, the gearing ratio was as follows:

	2022		2021
Total debt (Note 13)		94,614,065		102,421,012
Total equity		267,224,289		234,906,487
Total capital		361,838,354		337,327,499
Gearing Ratio		0.26		0.30

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

    16.2 Financial instruments by category and level of hierarchy

16.2.1 Categorization of financial instruments

The accounting policies for the categorization of financial instruments were explained in Note 4.e. In accordance with IFRS 7, IAS 32 and IFRS 9, non-financial assets and liabilities, such as contract and supplier liabilities, tax and social charges, income tax and deferred income tax are not included.

The categorization of financial assets and liabilities as of December 31, 2022 and 2021 is included below:

	December 31, 2022
	Financial assets at fair value		Financial assets at amortized cost		Total
CURRENT ASSETS
Trade receivables		-		16,939,295		16,939,295
Other receivables		-		4,359,818		4,359,818
Financial assets at amortized cost		-		1,438		1,438
Financial assets at fair value through profit or loss		39,289,630		-		39,289,630
Cash and cash equivalents		2,665,814		323,132		2,988,946
Total current assets		41,955,444		21,623,683		63,579,127
NON-CURRENT ASSETS
Other receivables		-		14,899		14,899
Other financial assets at amortized cost		-		40,162,283		40,162,283
Total non-current assets		-		40,177,182		40,177,182
Total assets		41,955,444		61,800,865		103,756,309

	Financial liabilities at fair value		Other financial liabilities		Total
CURRENT LIABILITIES
Trade payables		-		10,524,936		10,524,936
Loans		-		3,919,929		3,919,929
Payroll and social security taxes payables		-		2,153,524		2,153,524
Other payables		-		286,555		286,555
Total current liabilities		-		16,884,944		16,884,944
NON-CURRENT LIABILITIES
Loans		-		90,694,136		90,694,136
Total non-current liabilities		-		90,694,136		90,694,136
Total liabilities		-		107,579,080		107,579,080

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(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

	2021
	Financial assets at fair value		Financial assets at amortirzed cost		Total
CURRENT ASSETS
Trade receivables		-		20,693,854		20,693,854
Other receivables		-		3,151,559		3,151,559
Financial assets at amortized cost		-		3,721		3,721
Financial assets at fair value through profit or loss		25,844,992		-		25,844,992
Cash and cash equivalents		8,197,972		429,032		8,627,004
Total current assets		34,042,964		24,278,166		58,321,130
NON-CURRENT ASSETS
Other receivables		-		16,330		16,330
Financial assets at amortized cost		-		43,720,399		43,720,399
Total non-current assets		-		43,736,729		43,736,729
Total assets		34,042,964		68,014,895		102,057,859

	Financial liabilities at fair value		Other financial liabilities		Total
CURRENT LIABILITIES
Trade payables		-		11,820,683		11,820,683
Loans		-		2,299,738		2,299,738
Derivative financial results		82,329		-		82,329
Payroll and social security taxes payables		-		2,279,022		2,279,022
Other payables		-		619,970		619,970
Total current liabilities		82,329		17,019,413		17,101,742
NON-CURRENT LIABILITIES
Loans		-		100,121,274		100,121,274
Total non-current liabilities		-		100,121,274		100,121,274
Total liabilities		82,329		117,140,687		117,223,016

16.2.2 Fair value measurement hierarchy and estimates

According to IFRS 13, the fair value hierarchy introduces three levels of inputs based on the lowest level of input significant to the overall fair value. These levels are:

Level 1: includes financial assets and liabilities whose fair values are estimated using quoted prices (unadjusted) in active markets for identical assets and liabilities. The instruments included in this level primarily include balances in mutual funds and public or private bonds listed on the Bolsas y Mercados Argentinos S.A. (“BYMA”). Within this level, the Company includes those derivate financial instruments for which it was able to find an active market.

Level 2: includes financial assets and liabilities whose fair value is estimated using different assumptions quoted prices included within Level 1 that are observable for the asset or liability, either directly (i.e. as prices) or indirectly (for example, derived from prices).

Level 3: includes financial instruments for which the assumptions used in estimating fair value are not based on observable market information.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

During 2022 and 2021, there were no transfers between the different hierarchies used to determine the fair value of the Company’s financial instruments or reclassifications between categories of financial instruments.

The table below shows different assets at their fair value classified by hierarchy as of December 31, 2022 and 2021:

	As of December 31, 2022
	Level 1		Level 2		Level 3		Total
Financial assets at fair value
Cash and cash equivalents		2,665,814		-		-		2,665,814
Financial assets at fair value through profit or loss		39,289,630		-		-		39,289,630
Total		41,955,444		-		-		41,955,444

	As of December 31, 2021
	Level 1		Level 2		Level 3		Total
Financial assets at fair value
Cash and cash equivalents		8,197,972		-		-		8,197,972
Financial assets at fair value through profit or loss		25,844,992		-		-		25,844,992
Total		34,042,964		-		-		34,042,964

	Level 1		Level 2		Level 3		Total
Financial liabilities at fair value
Derivative financial instruments		82,329		-		-		82,329
Total		82,329		-		-		82,329

The fair value amount of the financial assets is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date.

As of December 31, 2022, the carrying amount of certain financial instruments used by the Company, in cash, cash equivalents, other investments, accounts receivable and payable and short-term obligations is representative of fair value due to the short-term nature of these instruments. Also, the carrying value of non-current financial assets measured at amortised cost consists of time deposits made with financial institutions at current market rates.

The estimated fair value of Non-current loans is estimated based on quoted market prices (level 1). The following table reflects the carrying amount and estimated fair value of the 2018 Notes at December 31, 2022, based on their quoted market price:

	As of December 31, 2022
	Carrying amount		Fair value
2018 Notes		84,229,875		77,460,798

17. REGULATORY FRAMEWORK

a) General framework of the natural gas transportation segment:

General aspects

Regarding tgs’ Natural Gas Transportation business, it is regulated by Law No. 24,076 (“the Natural Gas Act”), its regulatory Decree No. 1,738/92 and the Regulatory framework for the transportation and distribution of natural gas in Argentina. The Natural Gas Act created ENARGAS, which is entitled, among other things, to set the basis for the calculation, monitoring, approval of tariffs and the power to verify compliance with the Natural Gas Law and its regulations. On January 28, 2016, Resolution No. 7 of the MINEM of Argentina repealed the Resolution 2000/2005 of the former Ministry of MPFIPyS which provided that all tariff increases should have the prior intervention of the Undersecretary of Coordination and Management Control.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

tgs’ License has been granted for an original period of 35 years beginning on December 28, 1992. However, the Natural Gas Act provides that tgs may apply to ENARGAS for a renewal of its license for an additional period of ten years. ENARGAS should evaluate at that time the performance of tgs and raise a recommendation to the Executive Branch. At the end of the period of validity of the license, 35 or 45, as appropriate, the Natural Gas Act requires a call for a new tender for the granting of a new license, in which tgs, provided the Company fulfilled substantially with the obligations resulting from the license, would have the option of matching the best offer that the Government received in this bidding process.

Tariff situation

Prior the enactment of the Public Emergency Law, and according to the Regulatory Framework, transportation tariffs were to be calculated in US dollars and converted into Argentine pesos at the time the customer was billed using the exchange rate prevailing at the date of the billing. The basic natural gas transportation tariffs charged by tgs had been established at the time of the privatization of GdE and were to be adjusted, subject to prior authorization, in the following cases: (i) semiannually to reflect changes in the US producer price index (“PPI”) and (ii) every five years according to efficiency and investment factors determined by ENARGAS. The “efficiency factor” was a reduction to the base tariff resulting from future efficiency programs while the “investment factor” increased the tariffs to compensate the licensees for future investments which were not repaid through tariffs. Also, subject to ENARGAS approval, tariffs were to be adjusted to reflect non-recurrent circumstances or tax changes, other than income tax.

The terms and conditions as described in the precedent paragraph in connection with tariff adjustments contemplated within the Regulatory Framework are no longer effective since the enactment of the Public Emergency Law in early 2002, which, among other provisions, eliminated tariff increases based on US dollar exchange rate fluctuations, foreign price indexes or any other indexing procedure and established a conversion rate of one peso to one US dollar for tariffs. The Public Emergency Law also granted the Executive Branch power to renegotiate contracts entered into with private utility companies, pursuant to the framework included in such law as long as it is in force, which expired on December 31, 2017, after several extensions.

Between July 2003 and March 2018, the Company received a series of temporary tariff increases under the framework of the Integral Tariff Review (“RTI” for its acronym in Spanish) process initiated after the Public Emergency Law was passed.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

On March 27, 2018, the Executive Branch of the Argentine Government issued the Decree No. 250/2018 (the “Decree 250”) ratifying the 2017 Integral Agreement. This decree represents the conclusion of the RTI process and the completion of the 2017 Transitional Agreement, and thus, the final renegotiation of the license after seventeen years of negotiations.

The 2017 Integral Agreement sets the guidelines for the provision of the natural gas transportation service until the end of the License. Among these guidelines:

• The RTI Process, which will culminate in the signing of the integral agreement, was approved. As a result of this RTI, a new tariff schedule was also approved. This new tariff schedule applicable to the Company determined a total tariff increase of 214.2% and 37%, in the event that it had been granted in a single installment as of April 1, 2017, on the tariff of the natural gas transportation service and the CAU, respectively.

• The Five-Year Investment Plan was approved. Resolution 4362 obliged tgs for the execution of the Five-Year Plan, which requires a high level of essential investments for the operation and maintenance of the pipeline system, to provide quality, safe and reliable service. The Five-Year Plan shall be for the period from April 1, 2017 to March 31, 2022 and will amount to Ps. 6,786,543, expressed in December 31, 2016 currency terms.

• A non-automatic six-month adjustment mechanism for the natural gas transportation tariff and the investment commitments were approved. This adjustment must be approved by ENARGAS and for its calculation, the evolution of the WPI published by INDEC will be considered.

• tgs and its shareholders must withdraw any claim against the Government related to the natural gas transportation business, including the arbitration proceedings before the ICSID. The Company desisted from it on June 26, 2018.

As it is mentioned above the tariff increase was granted in 3 installments according to the following resolutions:

• Effective as of April 1, 2017, 64.2% of the tariff for the natural gas transport service, the CAU not being adjusted, in accordance with the provisions of Resolution No. 4362/2017 (“Resolution 4362”).

• Effective as of December 1, 2017, after the issuance of Resolution 120, 81.1% on the tariff for the natural gas transport service and 29.7% on the CAU, which includes the first adjustment by WPI.

• Effective as of April 1, 2018, an increase of 50% over the tariff for the natural gas transport service and the CAU within the framework of the provisions of Resolution No. 310/2018 issued by ENARGAS.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Semiannual tariff increase

This increase is granted within the framework of the semi-annual tariff adjustment of the natural gas transportation service in accordance with the provisions of the RTI process.

In the public hearing held on September 4, 2018, in which the Company requested, based on the variation of the WPI recorded for the period February - August 2018, a tariff increase of approximately 30%. Considering the hearing, on September 27, 2018, ENARGAS issued Resolution No. 265/2018 which determined a 19.7% tariff increase effective as of October 1, 2018.

This increase was determined by ENARGAS based on the simple average of the WPI, the Construction Cost Index for the period February and August 2018 and the Salary Variation Index between December 2017 and June 2018.

It is noteworthy that ENARGAS supported the determination of the aforementioned tariff increase in the provisions of Resolution 4362, which, among other issues, provided that under certain circumstances and macroeconomic conditions, such as the significant devaluation occurred after April 2018, ENARGAS may use other indexes than the WPI to determine the tariff increase. tgs notified ENARGAS its disagreement with respect to the methodology for calculating the semi-annual adjustment.

On March 29, 2019, ENARGAS issued Resolution No. 192/2019 (“Resolution 192”) that approved, effective as of April 1, 2019, a 26% increase in the tariff chart applicable to the public service of natural gas transportation by tgs in force as of March 31, 2019.

In accordance with current regulations, ENARGAS has considered the evolution of the wholesale price index update index (“WPI”) between the months of August 2018 and February 2019, in order to define the semi-annual adjustments applicable to tgs tariffs.

Regarding the semi-annual tariff adjustment that was to be enforced as from October 1, 2019, on September 3, 2019, the SE issued Resolution No. 521/2019 (“Resolution 521”) postponing it to February 1, 2020.

The deferral also meant that the Company reviewed and fit, in equal proportion to the revenue that is no longer received, the execution of the Five-Year Investment Plan. As of the date of the issuance of these Consolidated Financial Statements, tgs made the proposal to ENARGAS and the corresponding approval resolution have not yet been issued.

Nevertheless, the Solidarity Law establishes that natural gas transportation and distribution tariffs will remain unadjusted for a period of 180 as days from December 23, 2019. In this sense, the Executive Branch is authorized to renegotiate them, either within the framework of the current RTI or through an extraordinary review in accordance with the provisions of the Natural Gas Law.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

On June 9, 2020, through Resolution No. 80/2020, ENARGAS created the Coordination and Centralization Commission - Law No. 27,541 and Decree No. 278/20, which will have the purpose of coordinating the comprehensive tariff review process set forth in Article 5 of the Solidarity Law.

On June 19, 2020, the PEN issued Decree No. 543/2020 by which the natural gas transportation and distribution tariffs were extended without adjustments for an additional term of 180 calendar days, that is, until December 16, 2020.

By provision of the Necessity and Urgency Decree No. 1,020/2020 (“Decree 1,020”), ENARGAS, commissioned by the PEN, began the renegotiation of the RTI concluded in 2018, which may not exceed 2 years. Until then, the current renegotiation agreements are suspended. Said renegotiation remains in the power of ENARGAS ad referendum of the PEN.

In addition, Decree 1,020 extends the tariff freeze for an additional period of 90 calendar days or until transitory tariffs are approved. It should be noted that all agreements, whether transitory or general, entered into with the National Government must not only be subject to the public hearing procedures provided by the regulations in force, but also to the authorization of the different governmental agencies.

Additionally, the Solidarity Law provides for the administrative intervention of ENARGAS, recently extended through Decree 1,020.

On March 16, 2021, the public hearing convened by ENARGAS was held for the purposes of considering the Transitional Tariff Regime (“RTT”) in accordance with the provisions of Decree 1,020. In this regard, tgs, without renouncing the full percentage of tariff recomposition that corresponds to it, alternatively presented at this hearing a proposal for a tariff increase calculated by 58.6%, as of April 1, 2021. It was calculated based on the financial needs to meet the operating and financial costs, capital investments and taxes, which were calculated considering the evolution of the inflation rate for a period of 12 months from its inception. Such requested increase contemplated only the necessary funds to meet the obligations as a licensee.

Additionally, in such public hearing, tgs denied and dismissed the arguments raised in it that considered that the current natural gas transportation tariff is not fair and reasonable given the alleged existence of serious defects in the administrative acts derived from the processing of the last Regime Comprehensive Tariff (“RTI”) made for tgs.

On April 28, 2021, ENARGAS sent to tgs, a Transitory Agreement Project 2021 within the framework of the provisions of Decree 1,020. Said project provided:

• The non-granting of a temporary tariff increase, keeping the tariff schedules approved by ENARGAS in April 2019 unchanged.

• It established that from May 2021 and until the Definitive Renegotiation Agreement is in force, ENARGAS will proceed to re-calculate the transportation tariffs at that time in force with effect from April 1, 2022.

• It did not establish a mandatory investment plan.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

• The prohibition of: (i) distribution of dividends, (ii) an early cancellation of financial and commercial debts contracted with shareholders, and (iii) the acquisition of other companies or granting loans.

On April 30, 2021, through a note sent to that body, tgs stated that, given the context in which it develops its activities and the proposed terms and conditions, it was not feasible for the Company to sign the 2021 Temporary Agreement Project.

Subsequently, on June 2, 2021, ENARGAS issued Resolution No. 149/2021 (the “Resolution 149”) approving an RTT for tgs effective as of that date. The RTT (i) does not grant a temporary tariff increase in favor of the Company, but the current tariff schedules in force since April 1, 2019 remain unchanged; (ii) provides that from the entry into force of the Transitional Regime -and until the Definitive Renegotiation Agreement is in force- the possibility is contemplated that ENARGAS adjusts the rates of tgs as of April 1, 2022 ; (iii) does not establish a mandatory investment plan for tgs and (iv) establishes the prohibition to distribute dividends and prepay financial and commercial debts contracted with shareholders, acquire other companies or grant loans.

In July 2021, tgs filed appeals for reconsideration with the PEN, the Ministry of Economy of the Nation and ENARGAS with an appeal or hierarchical subsidy in accordance with the respective powers of each of these bodies in the dictation of the entire regulatory plexus associated with Resolution 149, (Decree 1020/20, Decree 353/21, and Joint Resolution No. 1/2021), requesting that the RTT be declared null and void and the RTI be restored. We recall that the RTT began with Decree 1020/20, which set the guidelines to carry out the renegotiation of the RTI, later issuing Joint Resolution 1/21, which sets the RTT, and Decree 353/21, which approved Joint Resolution 1 /21, and culminates with Resolution 149, which approved the new tariff charts.

The challenges are based on: i) the illegality of Decree 1020 because it does not follow the lines of the delegation provided for in Law 27,541, and as a Decree of Necessity and Urgency it does not comply with the requirements of the Constitution for the issuance of this regulation; ii) the extension of the emergency beyond that provided by Congress; iii) the failure to carry out the tariff renegotiation as provided for in Law 24. 076; iv) the disregard of the principle of fair and reasonable tariffs, and the acquired rights of tgs in the License, the Contractual Adjustment Agreement and the RTI; and v) the suspension of the RTI for reasons of public interest, which merits the recognition of the compensations, provided by both the Administrative Procedures Law and the Basic Rules of the License.

The restrictions imposed on the management and management of the Company, which have no legal justification, are also questioned, given that the emergency declared by Law No. 27,541 only empowered the National Executive Power to renegotiate the RTI and not the License.

The challenges and the request for reinstatement of the RTI have been made without prejudice to the right of tgs to pay the compensation that corresponds to it for not having complied with the RTI since April 2019.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

On November 15, 2021, the Company filed a Prior Administrative Claim before ENARGAS and the Ministry of Economy. The purpose of said presentation is to request the compensation that corresponds to tgs for the lack of application of the semi-annual adjustment methodology established in the RTI approved by Resolution 362 between October 1, 2019 and June 1, 2021.

In addition, payment of compensation for the damages suffered by tgs due to the freezing caused by the failure to apply the six-monthly adjustment methodology established in the RTI in the aforementioned period is requested.

On January 19, 2022, a new public hearing was held, within the framework of ENARGAS Resolution No. 518/2021, whose purpose was to deal with a transitory tariff adjustment within the framework of Decree 1020/2020. In such hearing, with the purpose of reaching a definitive agreement on the renegotiation and recomposing the license economic-financial equation, tgs requested a transitory tariff adjustment applied in two stages for the year 2022 for a total of 106%, due to the evolution of operating costs and the main macroeconomic indicators.

Subsequently, on February 1, 2022, tgs received from ENARGAS a proposal for a Transitional Renegotiation Agreement (the “2022 Transition Agreement”) which was approved by our Board of Directors on February 2, 2022 and by the corresponding government agencies on February 18, 2022. The 2022 Transition Agreement includes, in some aspects, similar terms to the 2021 RTT with the particularity that it grants tgs a 60% tariff increase effective as from March 1, 2022 (the “RTT 2022”).

The 2022 Transition Agreement was ratified by the PEN through Decree No. 91/2022, which entered into force as from February 23, 2022. On February 25, 2022, the ENARGAS issued Resolution No. 60/2022 by which it put into effect the tariff schedules that contemplate the RTT 2022.

It should be noted that, in accordance with the provisions of the 2022 Transition Agreement, tgs committed not to initiate new claims, appeals, actions, lawsuits or demands of any kind; and/or to suspend, keep suspended or extend the suspension of all appeals and claims filed that are related in any way to the Renegotiation of the Comprehensive Tariff Review in force, Law No. 27,541, Decrees No. 278/20 and No. 1020. Under Decrees 1020 and 815, on December 7, 2022, ENARGAS issued Resolution No. 523/2022 which called for a public hearing on January 4, 2023 to, among other issues, consider the transitory adjustment of tariffs for the public natural gas transportation service.

As of the date of issuance of these Consolidated Financial Statements, the Company is working together with ENARGAS to carry out the RTI process that will allow it to receive a fair and reasonable tariff according to the natural gas transportation public service provided.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

b) General Framework for non-regulated segments

Domestic market

The Production and Commercialization of Liquids segment is not subject to regulation by ENARGAS, and as it is provided in the Transfer Agreement, is organized as a separate business unit within tgs, keeping accounting information separately. However, over recent years, the Argentine Government enacted regulations which significantly impacted on it.

In April 2005, the Argentine Government enacted Law No. 26,020 which sets forth the regulatory framework for the industry and commercialization of LPG. Among other things, the Law No. 26,020 creates the framework through which the Secretary of Hydrocarbon Resources (“SHR”) (formerly the Federal Energy Bureau) establishes regulations meant to cause LPG suppliers to guarantee sufficient supply of LPG in the domestic market at low prices. Law No. 26,020 creates a price regime pursuant to which the SRH periodically publish reference prices for LPG sold in the domestic market. It also sets forth LPG volumes to be sold in the domestic market.

Within this framework, tgs sells propane and butane production to fractionators at prices determined every six months. On March 30, 2015, the Executive Branch issued Decree No. 470/2015, regulated by Resolution No. 49/2015 issued by the Federal Energy Bureau, which created the Programa Hogares con Garrafa (the “Households with Bottles Program”) which replaced the programs in force until that time. The Households with Bottles Program was implemented through Resolutions No. 49/2015 and No. 470/2015 issued by the Federal Energy Bureau.

Within the framework of the Households with Bottles Program, a maximum reference price was determined for the members of the commercialization chain in order to guarantee the supply to low-income residential users, forcing producers to supply with LPG at a certain price and at a certain quantity defined for each of them. Additionally, the payment of compensation to the participating producers of the Households with Bottles Program was established.

During 2020 and in accordance with Decree 311, the maximum reference prices for the commercialization of liquefied petroleum gas (LPG), which the Company sells in the domestic market, remained unchanged for a period of 180 calendar days from its issuance. On October 19, 2020, the Energy Secretariat issued Resolution 30/2020 by which it increased the price of such products to Ps. 10,885 (in accordance with the provisions of said resolution).

During 2021, the Secretary of Energy issued Resolution No. 249/2021 by which it increased the prices as from April 6, 2021 to Ps. 12,626.60 (in accordance with the provisions of said resolution).

During 2022, the SE, through Resolutions No. 270/2022 and 609/2022, ordered increases in the price of the products that are marketed within the framework of this program. The last one, as of September 2022, raised it to Ps.18,375.49 per ton (according to Resolution 609).

In this context, the Company has filed several administrative and judicial claims challenging the general regulations of the Home Plan, as well as the administrative acts that determine the volumes of butane to be sold in the local market, in order to safeguard its economic-financial situation and so that such situation does not continue in time.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Additionally, the Company participates in the Propane Gas Supply Agreement for Indiluted Propane Gas Distribution Networks (“Propane for Networks Agreement”) entered into with the Argentine Government and propane producing companies whereby it undertakes to supply propane to distributors and sub-distributors of indiluted propane gas through networks at a price lower than the market price, The Company receives an economic compensation for the lower revenues derived from the participation in this program, which is calculated as the difference between the agreed sales price and the reference export parity price determined by the Energy Secretariat.

Within the framework of the path of gradual reduction of subsidies provided by the former MINEM, on March 31, 2017 the former MINEM issued Resolutions No. 74/2017 (“Resolution 74”) and No. 474-E/2017 (“Resolution 474”) by which an increase in the price of indiluted propane gas destined to the Propane for Networks Agreement is provided as from April 1 and December 1, 2017, respectively. As from such dates the price paid by the customer was set at Ps. 1,267/tn and Ps. 2,832/tn (as provided by Resolution 74) and Ps. 1,941.20/tn and Ps. 3,964/tn (as provided by Resolution 474), respectively, depending on the customer to whom the product is destined.

Finally, in May 2018 tgs entered into the sixteenth extension to the Propane Agreement for Networks which served as a framework for the commercialization of the products stipulated therein for the period April 1, 2018 - December 31, 2019. Additionally, this last extension fixed the price at which the propane destined to this program was marketed to the customer. Notwithstanding the foregoing, on January 14, 2020 tgs received the instruction issued by the Secretary of Energy to proceed with the propane deliveries according to the conditions of the sixteenth extension of the Propane for Networks Agreement. Subsequently, the Company entered into the seventeenth extension to the Propane for Networks Agreement, effective until December 31, 2020. On August 10, 2021, tgs celebrated the eighteenth extension of the Propane Agreement for Networks, valid until December 31, 2021. On February 17, 2022, tgs celebrated the nineteenth extension of the Propane for Networks Agreement, valid until December 31, 2022.

As mentioned above, participation in the Plan Hogar implies economic-financial losses for the Company, since under certain circumstances the sale of the products would be made at prices below production costs.

As of December 31, 2022, the Argentine State owes tgs Ps. 3,768,159 for these concepts.

Foreign market

On September 3, 2018, the Executive Branch issued Decree No. 793/2018, which, between September 4, 2018 and December 31, 2020, sets an export duty of 12% on the exported amount of propane, butane and natural gasoline. This withholding is capped at $4 for each dollar of the tax base or the official FOB price.

Subsequently, on the occasion of the enactment of the Solidarity Law, an 8% cap was established for the rate applicable to hydrocarbons as of December 23, 2019.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Presidential Decree No. 488/2020 regulated the applicable tax rate on exports of certain oil and gas products, including those products that we export, establishing a range between 0% and 8% depending on the “ICE Brent first line” barrel price. If the price is below US$ 45, the tax rate will be zero percent . On the other hand, if the price is equal to or higher than US$ 60, an 8% tax rate will be paid, being variable if the price is between US$ 45 and US$ 60.

Decree No. 2,067 / 08

Through Presidential Decree No. 2,067/08, the Executive Branch created a tariff charge to be paid by: (i) the users of regulated services of transportation and / or distribution, (ii) natural gas consumers receiving natural gas directly from producers without making use of transportation systems or natural gas distribution, (iii) the natural gas processing companies in order to finance the import of natural gas. The tariff charge sets forth in this decree finance the higher price of the natural gas imports required to compensate the injection of natural gas necessary to meet national requirements (the “Charge”). When the Charge was created, tgs paid it in accordance with the provisions of Resolution I-563/2008, at Ps. 0.0492/m3.

The payment of the natural gas processing tariff charge was selectively subsidized from 2008 according to the destination of the natural gas. In November 2011, however, ENARGAS issued Resolution No. 1,982/11 and 1,991/11 (the “Subsidy Beneficiaries Resolutions”) which modified the list of the subsidy beneficiaries, and thus, involved a cost increase for many of our clients and for us (for certain of our consumption for our own account). The natural gas processing tariff charge increased from Ps. 0.0492 to Ps. 0.405 per cubic meter of natural gas effective from December 1, 2011, representing a significant increase in our variable costs of natural gas processing.

In order to avoid this damage, tgs appealed against the Presidential Decree and the Resolutions including National Government, ENARGAS and ex MPFIPyS as defendants.

For further information regarding the legal action filed the Company, see Note 20.b).

On March 28, 2016, the former MINEM issued Resolution No. 28/16 (“Resolution 28”), which instructs ENARGAS to take all the necessary measures to derogate the tariff charge created by Decree No. 2,067/08 as from April 1, 2016. However, such Resolution does not repeal or declare illegitimate this decree and the Subsidy Beneficiaries Resolutions for which the judicial action is still ongoing.

c) Essential assets

A substantial portion of the assets transferred by GdE has been defined as essential for the performance of the natural gas transportation service. Therefore, tgs is required to keep separated and maintain these assets, together with any future improvements, in accordance with certain standards defined in the License.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

tgs may not, for any reason, dispose of, encumber, lease, sublease or loan essential assets nor use such assets for purposes other than the provision of the licensed service without ENARGAS´s prior authorization. Any expansion or improvements that it makes to the gas pipeline system may only be encumbered to secure loans that have a term of more than one year to finance such extensions or improvements.

Upon expiration of the License, tgs will be required to transfer to the Argentine government or its designee, the essential assets listed in an updated inventory as of the expiration date, free of any debt, encumbrances or attachments. If the Company decides not to continue with the license, tgs will receive a compensation equal to the lower of the following two amounts:

i) The net book value of the essential assets determined on the basis of the price paid by the acquiring joint arrangements, and the original cost of subsequent investments carried in US dollars and adjusted by the PPI, net of accumulated depreciation according to the calculation rules to be determined by ENARGAS; or

ii) The net proceeds of a new competitive bidding (the “New Bidding”).

Once the period of the extension of the License expires, tgs will be entitled to participate in the New Bidding, and thus, it shall be entitled to:

(i) That its bid in the New Bidding be computed at an equal to the appraisal value to be determined by an investment bank selected by ENARGAS, which represents the value of the business of providing the licensed service as it is driven by the Licensee at the valuation date, as a going concern and without regard to the debts;

(ii) To obtain the new License, without payment, in the event that any bid submitted in the New Bidding exceeds the appraised value;

(iii) To match the best bid submitted by third parties in the New Bidding, if it would be higher than its bid mentioned in (i), paying the difference between both values ​​to obtain the new License;

(iv) If the Company is unwilling to match the best bid made by a third party, to receive the appraisal value mentioned in (i) as compensation for the transfer of the Essential Assets to the new licensee.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

18. ASSETS AND LIABILITIES IN FORREIGN CURRENCY

The balances in foreign currency as of December 31, 2022 and 2021 are detailed below:

	2022							2021
	Foreign currency					Amount		Foreign currency		Amount
	and amount		Exchange			in local		and amount		in local
	(in thousands)		rate			currency		(in thousands)		currency
CURRENT ASSETS
Cash and cash equivalents	US$	1,613		176.960	(1)		285,436	US$	1,512		301,949
Financial assets at fair value through profit or loss (3)	US$	176,852		176.960	(1)		31,295,730		65,522		13,084,872
Trade receivables	US$	66,107		176.960	(1)		11,698,295	US$	66,395		13,259,212
Total current assets	US$	244,572					43,279,461	US$	133,429		26,646,033
NON CURRENT ASSETS
Financial assets at amortized cost (4)	US$	226,957		176.960	(1)		40,162,283	US$	218,917		43,718,092
Total non current assets	US$	226,957					40,162,283	US$	218,917		43,718,092
TOTAL ASSETS	US$	471,529					83,441,744	US$	352,346		70,364,125
CURRENT LIABILITIES
Trade payables	US$	38,655		177.160	(2)		6,848,120	US$	37,807		7,564,861
	Euros	432		189.916	(2)		82,043		-		-
Loans	US$	21,819		177.160	(2)		3,865,516	US$	11,493		2,299,738
	Euros	287		189.916	(2)		54,413		-		-
Total current liabilities	US$	60,474					10,713,636	US$	49,300		9,864,599
	Euros	719					136,456		-		-
NON CURRENT LIABILITIES
Loans	US$	511,933		177.160	(2)		90,694,136	US$	500,377		100,121,274
Contract liabilities	US$	10,106		177.160	(2)		1,790,361		-		-
Total non current liabilities	US$	522,039					92,484,497	US$	500,377		100,121,274
TOTAL LIABILITIES	US$	582,513					103,198,133	US$	549,677		109,985,873
	Euros	719					136,456		-		-

⁽¹⁾ Buy exchange rate at the end of fiscal year

⁽²⁾ Sell exchange rate at the end of fiscal year

⁽³⁾ Includes public and private debt bonds Dólar Linked for Ps. 27,013,330.

⁽⁴⁾ Includes time deposits Dólar Linked for Ps. 865,009.

US$: United States of America dollars

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

19. COMMON STOCK AND DIVIDENDS

a) Common stock structure and shares’ public offer

As of December 31, 2022, 2021 and 2020, tgs’ common stock was as follows:

Common Stock structure as of December 31, 2022, 2021 and 2020
Shares Class	Amount of common stock, subscribed, issued, paid in, and authorized for
	public offer
Common Shares Class
(Face value $ 1, 1 vote)	Outstandings shares		Treasury Shares		Common Stock
Class “A”		405,192,594		-		405,192,594
Class “B”		347,568,464		41,734,225		389,302,689
Total		752,761,058		41,734,225		794,495,283

tgs’s shares are traded on the BYMA and under the form of the American Depositary Receipts (“ADS”) (registered in the SEC and representing 5 shares each) on the New York Stock Exchange.

b) Acquisition of treasury shares

On March 6, 2020, the Company’s Board of Directors approved the sixth Program for the Acquisition of tgs treasury Shares in the markets where it makes a public offering of its shares (the “Sixth Repurchase Program”) for a maximum amount of Ps. 2,500 million (at the time of its creation).

Subsequently, on August 21, 2020, the Board of Directors approved a new Program for the Acquisition of tgs’ treasury Shares for a maximum amount to be invested in Ps. 3,000 million (at the time of its creation). This program will run until March 22, 2021.

The acquisition cost of the treasury shares in portfolio amounted to Ps. 10,924,539, which, together with the trading premium on treasury shares of Ps. 3,169,112, in accordance with the provisions of Title IV, Chapter III, article 3.11.c and e of the Rules, restricts the amount of realized and liquid gains that the Company may distribute.

c) Restrictions on distribution of retained earnings

Pursuant to the General Companies Act and CNV Rules, we are required to allocate a legal reserve (“Legal Reserve”) equal to at least 5% of each year’s net income (as long as there are no losses for prior fiscal years pending to be absorbed) until the aggregate amount of such reserve equals 20% of the sum of (i) “common stock nominal value” plus (ii) “inflation adjustment to common stock,” as shown in our consolidated statement of changes in equity.

Finally, and as mentioned in subsection b of this note, the amounts subject to distribution are restricted up to the acquisition cost of treasury shares and the paid-up capital.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

In addition, according with the 2022 Transitional Agreement, tgs may not distribute dividends meanwhile it will be in force.

20. LEGAL CLAIMS AND OTHER MATTERS

a) Turnover tax calculated on the natural gas price consumed by tgs

The Company has interpretative differences with several provinces regarding the liquidation of the turnover tax calculated on the natural gas used by tgs as fuel to render its transportation services. In this framework there have been initiated several lawsuits against tgs, which have adversely concluded by the Company.

As of December 31, 2022 and 2021, the Company has recorded a provision for these concepts of Ps. 1,657.4 million and Ps. 2,210.7 million, respectively, recorded in the caption “Provisions”, determined based on the estimated tax and interest payable as of such date, in the event that these claims from the provinces are unfavorable for tgs.

b) Action for annulment of ENARGAS Resolutions No. I-1,982/11 and No. I-1,991/11 (the “Resolutions”)

After the issuance of the Resolutions, tgs filed a judicial action before the National Court of First Instance in Federal Administrative Litigation No. 1 (the “Court”) in order to obtain the declaration of nullity of the Presidential Decree No. 2067/08 and the Resolutions as well as the unconstitutionality of the administrative acts that created the Charge.

On July 5, 2012, the Court issued in favor of tgs a precautionary measure by which the suspension of the Charge was ordered in the terms set forth in the Resolutions. This decision was appealed in different opportunities by the National Government, by virtue of which the dictating of the precautionary measure was limited to the validity of six months. However, at maturity, the Company is entitled to obtain a new precautionary measure for a similar period.

As a result, on September 19, 2017, a new extension of the injunction was obtained (which prevented the Government to claim tgs of the payment of the amounts resulting from the new value of the Charge for the period between the November 2011 and March 2016), thus extending the validity until March 2018.

On the other hand, the National Court of Appeals in Contentious Administrative Dismissal rejected the extraordinary appeal filed by the National Government against the judgment of that court that confirmed the rejection made by the Court at the request of ENARGAS to declare abstract the legal action initiated by tgs in accordance with the precedent “Alliance” issued by the Supreme Court in December 2014.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

On March 26, 2019, tgs was notified of the judgment of first instance issued by the Federal Contentious-Administrative Court No. 1 in its claim initiated by which tgs requested the unconstitutionality of Decree No. 2,067/08; Resolutions and of any other rule or act issued or to be issued, that is caused by the mentioned rules (the “Cause”).

The first instance judgment declares the unconstitutionality of both Articles 53 and 54 of Law 26,784, as well as the aforementioned rules and of any other act tending to execute said provision, and consequently, the nullity of said rules (the “sentence”).

The Judgment was appealed by the National Government on March 29, 2019, and the appeal was granted on April 3, 2019, which has not been resolved as of the closing date of the year.

On October 29, 2019, the intervening judge decided, considering what was decided in the judgment and attending to the reasons invoked by tgs, to extend the validity of the precautionary measure issued for six more months of processing in said ordinary process and / or until the sentence passed is firm.

Pursuant to the isolation measures adopted by the Argentine Government under the COVID development, the judicial deadlines were suspended from March 20, 2020 until July 21, 2020. Considering that the six-month term should not be computed during fair periods, the remaining term of 2 months and 9 days was completed on September 29, 2020.

On December 1, 2020, the court granted a new extension of said injunction for a term of 6 months.

On May 14, 2021, tgs was notified of the ruling issued by Chamber I of the Chamber in Contentious-Administrative Matters that (i) has revoked the decision by the Judge of First Instance and (ii) has imposed the costs in both instances in the order caused. tgs considers that it has reasonable arguments to defend its position on the substantive issue raised and, for that reason, it appealed the judgment of the Chamber.

On June 4, 2021, tgs filed an extraordinary federal appeal against the judgment of the Chamber, which was contested by ENARGAS and the National State, and was granted by the Court of Appeals itself on July 14, 2021, on the understanding that “At stake is the interpretation and scope of regulations of an unquestionable federal nature, such as Decree 2067/08 and MINPLAN Resolution No. 1451/2008, ENARGAS Resolutions No. 1982/11 and 1991/11, as well as articles 53 and 54 of Law 26,784”.

By virtue of the precautionary measure issued, and its 12 extensions obtained, as well as the favorable judgment obtained in the first instance, the existence of favorable precedents issued by the Supreme Court of Justice of the Nation (“Supreme Court”) with respect to other processors of natural gas and the granting of the extraordinary appeal that will give rise to the Supreme Court ruling on the case, the management of tgs and its legal advisors consider that they have solid arguments to defend their position and that it is probable that a favorable resolution will be obtained for their interests on the substantive issue raised. Therefore, no provision has been made for the eventual liabilitie due to the increase in the charge to finance the importation of natural gas applicable to natural gas consumption related to the processing activity at the Cerri Complex for the period between the date of obtaining the measure precautionary and on April 1, 2016, date of entry into force of Resolution No. 28/2016.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

This resolution has annulled the acts that determined the value of the charge established by Decree 2067, for which as of April 1, 2016, ENARGAS and the agency in charge of its collection have stopped charging the increase established by the Resolutions.

Regarding the last extension of the precautionary measure, expired on July 1, 2021, tgs has not requested a new extension, due to the premature procedural stage in which the appeal filed against the judgment of the Chamber is found.

Given the complex procedural instance, the nature of charge 2067, the background information presented in this and other legal cases initiated against charge 2067, at the date of the issuance of these Consolidated Financial Statements it is not possible to make a definitive quantification of the amount that should be pay tgs in the event of not obtaining a favorable ruling from the Supreme Court, while an eventual request for payment in the current circumstances may be challenged and questioned by tgs within the framework of the corresponding administrative and judicial instances, where the amount may be debated of the charge that is eventually required to tgs.

c) Recovery action of VAT and income tax

On October 9, 2008, tgs signed the 2008 Transitional Agreement with ex UNIREN that contemplated a tariff increase of 20%, applicable as from September 1, 2008. On December 3, 2009, the Executive Branch ratified this transitional agreement through the Presidential Decree No. 1,918/09. By means of this decree, tgs was able to bill the tariff increase to its clients as soon as ENARGAS would have published the new tariffs schedule and set the methodology to bill the retroactive effect. Finally, this administrative act did not become effective and therefore in September 2010 tgs filed an acción de amparo (a summary proceeding to guarantee constitutional rights). Due to the passing of time since the enactment of Decree No. 1918/09, on December 16, 2010, the Board of Directors of the Company resolved to discontinue the recognition of the tariff increase revenue and to reverse the receivable of the tariff increase revenue already accrued. The reversal of the tariff increase did not imply any resignation to the Company´s rights resulting from the Decree No. 1,918/09.

On May 24, 2013, tgs filed a tax recovery appeal with respect to the income tax and VAT credits generated by the reversal of the tariff increase credit mentioned above. The total amount claimed by tgs amounted to Ps. 102.5 million plus compensatory interests. After the omission to pass judgment on the claim within the three months of the filing of the tax recovery appeal, on October 9, 2013, tgs filed an appeal before the Federal Tax Bureau. On June 6, 2017, the Tax Court of the Nation rejected the claim for recovery filed by the Company. This resolution was appealed by tgs.

On May 7, 2019, the National Court of Appeals for Federal Administrative Disputes made the appeal filed by tgs and revoked the judgment of first instance, with costs to the defeated defendant. On May 23, 2019, the Treasury filed an Extraordinary Appeal - which was granted on September 26, 2019 in relation to the interpretation of the federal norms at stake in the case, but was denied as to the arbitrariness of judgment - and then Complaint Appeal.

On August 5, 2021, the Supreme Court confirmed the ruling of Chamber I of the Federal Contentious-Administrative Chamber in favor of tgs, which is final.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

After having made the corresponding presentations before the AFIP, the Company proceeded to offset the credit (capital plus interest) generated with the payment of taxes as established by the tax agency.

d) Turnover tax withholding in the Province of Buenos Aires

The Company was notified by ARBA regarding the initiation of various determinative procedures in which tgs is claimed for a total of Ps. 4.9 million (without fine or interest) for the omission as agent of withholding and collection of the turnover tax corresponding to the period July 2009 - June 2011. Given this determination, the Company presented to ARBA various elements of evidence that allow reducing substantially the amount claimed. As of the date of issuance of these consolidated financial statements, the Tax Court has not resolved the issue.

In March 2017, tgs partially canceled the debt claimed by ARBA, paying Ps. 2.9 million (stated in its original value) through the adhesion to the payment plans offered by the Province of Buenos Aires through Law 14,890. Adherence to these payment plans allowed partial cancellation of compensatory interest and all fines and charges claimed by ARBA.

As of the date of the issuance of these Consolidated Financial Statements, only two files remain in relation to the alleged failure of tgs to act as withholding and collection agent during 2009 and 2010. The Company’s Management considers that it has sufficient arguments to assert its defense so at December 31, 2022 and 2021 and no provisions have been recorded for this concept.

e) Environmental matters

The Company is subject to extensive environmental regulations in Argentina. Management believes that its current operations are in material compliance with applicable environmental requirements, as currently interpreted and enforced. The Company has not incurred in any material environmental liabilities as a result of its operations to date. As of December 31, 2022 and 2021, the total amount of these provisions amounted Ps. 58.5 million and 92.3 million, respectively.

f) Others

In addition to the matters discussed above, the Company is a party to certain lawsuits and administrative proceedings which involve taxation, labor claims, social security, administrative and others arising in the ordinary course of business. The Company’s Management and its legal advisors estimate that the outcome of these differences will not have significant adverse effects on the Company’s financial position or results of operations. As of December 31, 2022 and 2021, the total amount of these provisions amounted Ps. 77.4 million and Ps. 221.5 million, respectively

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

21. BALANCES AND TRANSACTIONS WITH RELATED COMPANIES

Technical, Financial and Operational Assistance Agreement

Pampa Energía is tgs’s technical operator, according to the approval of ENARGAS in June 2004, and subject to the terms and conditions of the Technical Assistance Agreement which provides that Pampa Energía is in charge of providing services related to the operation and maintenance of the natural gas transportation system and related facilities and equipment, to ensure that the performance of the system is in conformity with international standards and in compliance with certain environmental standards. For these services, the Company pays a monthly fee based on a percentage of the operating income of the Company.

The Ordinary and Extraordinary General Shareholders´ Meeting held on October 17, 2019 ratified the proposal approved by the Board of Directors at its meeting on September 17, 2019 made to Pampa Energía that implies an extension in the contract and a modification in the determination of the remuneration received by Pampa Energía.

Such modifications, without implying a modification in the scope of the tasks performed, will mean a progressive reduction over the years in the remuneration that Pampa Energía will receive in its role of Technical Operator.

According to the modifications made, tgs will pay Pampa Energía the greater of: (i) an annual fixed sum of US$ 0.5 million or (ii) the variable compensation that arises from applying to comprehensive income before results and income taxes for the year but after deducting also the above fixed amount) the following scheme:

• From 12/28/2019 to 12/27/2020: 6.5%

• From 12/28/2020 to 12/27/2021: 6%

• From 12/28/2021 to 12/27/2022: 5.5%

• From 12/28/2022 to 12/27/2023: 5%

• From 12/28/2023 to 12/27/2024 and onwards: 4.5%

Commercial transactions

In the normal course of its activity, tgs celebrated with Pampa Energía and other companies related to it, agreements to transfer natural gas and its richness. The price, which is denominated in US dollars, is determined according to common market practices.

In addition, in the normal course of business, tgs carries out liquid sales, natural gas transportation services and other services with its associated companies, Pampa Energía and related companies.

Financial lease agreement with Pampa Energía

As mentioned in Note 13 to these Consolidated Financial Statements, on August 11, 2016, the Company entered into a finance lease agreement with Pampa Energía (formerly Petrobras Argentina).

Key management compensation

The accrued amounts corresponding to the compensation of the members of the Board of Directors, the Statutory Committee and the Executive Committee for the years ended December 31, 2022, 2021 and 2020 were Ps. 427,015, Ps. 400,832 and Ps. 406,894, respectively.

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Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Balances and transactions with related parties

The detail of significant outstanding balances for transactions entered into by tgs and its related parties as of December 31, 2022 and 2021 is as follows:

	2022				2021
Company	Accounts receivable		Accounts payable		Accounts receivable		Accounts payable
Controlling shareholder:
CIESA		37		-		-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía (1)		1,299,505		4,889,458		659,046		6,830,195
Associate which exercises significant influence on the controlling shareholder:
Link		4,683		-		5,088		-
TGU		-		28,199		-		31,849
Other related companies:
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		19,695		17,518		24,165		35,932
CT Barragán S.A.		4,294		-		7,385		-
SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A.		2,227		-		-		-
Transener S.A.		30		-		-		61
Total		1,330,471		4,935,175		695,684		6,898,037

⁽¹⁾ Accounts payable includes Ps. 4,262,215 and Ps. 5,887,648 corresponding to the financial leasing recorded as “Loans” as of December 31, 2022 and 2021, respectively.

Additionally, during the year ended December 31, 2022, the Company received from SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A., construction engineering services for Ps. 3,318,934 which are activated within the balance of advances to suppliers.

As of December 31, 2022 and 2021, tgs has a balance of Ps. 2,570,796 and Ps. 1,388,558 corresponding to Dollar linked notes issued by CT Barragán S.A. that accrue an annual rate of 4% over the exchange rate established in BCRA Communication “A” 3500 and that amortize the entire capital in June 2023, November 2024 and May 2025. The book value of the notes is disclosed within the caption “Financial assets at fair value through profit or loss”.

The detail of significant transactions with related parties for the years ended December 31, 2022, 2021 and 2020 is as follows:

Year ended December 31, 2022:

			Revenues				Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense		Interest gain / Gain / (loss) on fair value	Selling expenses (1)
Controlling shareholder:
CIESA		-		-		-		-		-		-		162	-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		1,471,413		3,583,230		3,972,829		5,826,231		3,067,198		-		-	-		-
Associates with significant influence:
Link		-		-		46,750		-		-		-		-	-		-
Other related companies:
SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A.		-		-		7,203		-		-		-		-	-		-
Transener S.A.		-		-		417		-		-		-		-	-		-
CT Barragán S.A.		-		-		17,459		-		-		-		-	96,408		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		298,568		-		-		-		-		-		-	-		-
Fundación TGS		-		-		-		-		-		-		-	-		31,059
Total		1,769,981		3,583,230		4,044,658		5,826,231		3,067,198		-		162	96,408		31,059

⁽¹⁾ Corresponds to donations expenses.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Year ended December 31, 2021:

			Revenues				Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense		Interest gain / Gain / (loss) on fair value		Selling expenses (1)
Controlling shareholder:
CIESA		-		-		-		-		-		277		-		-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		1,666,555		4,996,215		2,365,465		5,628,181		4,250,358		-		568,315		-		-
Associates with significant influence:
Link		-		-		-		-		-		-		-		-		-
Other related companies:
Oleoductos del Valle S.A.		51,542		-		54,102		-		-		-		-		-		-
Transener S.A.		-		-		701		-		-		-		-		-		-
CT Barragán S.A.		-		-		26,659		-		-		-		-		484,082		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		289,761		-		-		-		-		-		-		-		-
Fundación TGS		-		-		-		-		-		-		-		-		2,277
Total		2,007,858		4,996,215		2,446,927		5,628,181		4,250,358		277		568,315		484,082		2,277

⁽¹⁾ Corresponds to donations expenses.

Year ended December 31, 2020:

	Revenues						Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense
Controlling shareholder:
CIESA		-		-		-		-		-		411		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		2,473,548		3,087,152		1,807,202		470,636		4,205,901		-		712,528
Associates with significant influence:
Link		-		-		57,517		-		-		-		-
Other related companies:
Oleoductos del Valle S.A.		75,765		-		-		-		-		-		-
Transener S.A.		-		-		1,034		-		-		-		-
Petrolera Entre Lomas S.A.		7,277		-		26,268		-		-		-		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		331,583		-		-		-		-		-		-
Central Térmica Piedrabuena S.A.		5,131		-		-		-		-		-		-
Total		2,893,304		3,087,152		1,892,020		470,636		4,205,901		411		712,528

22. CONTRACTUAL OBLIGATIONS

a) Contractual Commitments

As of December 31, 2022, the Company had the following contractual commitments:

	Estimated maturity date
	Total		Due less than one year		As of 12/31/2023		From 01/01/2024 to 12/31/2024		From 01/01/2025 to 12/31/2025		From 01/01/2026 to 12/31/2026
Financial indebtedness (1)		109,769,494		-		7,848,106		10,351,813		91,569,575		-
Purchase obligations (2)		18,144,797		-		16,289,422		1,855,375		-		-
Financial Leases		4,901,101		133,549		1,325,156		1,325,334		1,325,334		791,728
Total		132,815,392		133,549		25,462,684		13,532,522		92,894,909		791,728

⁽¹⁾ Corresponds to the cancellation of principal and interest of the financial indebtedness. For further information, see Note 13.

⁽²⁾ Corresponds to purchase of natural gas contracts for the processing of liquids.

The totality of the financial indebtedness of tgs and the obligations corresponding to gas purchases are denominated in U.S. dollars which have been translated into Argentine pesos at the exchange rate as of December 31, 2022 (US$ 1.00 = Ps. 177.16). The amounts to be paid in pesos could vary depending on the actual fluctuations in the exchange rate.

b) Guarantees granted and goods for restricted availability

The Company has not granted any additional guarantees or goods of restricted availability other than those set out in the remaining notes.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

23. ASSOCIATES AND JOINT ARRANGEMENTS

Link:

Link was created in February 2001, with the purpose of the operation of a natural gas transportation system, which links tgs’s natural gas transportation system with the Cruz del Sur S.A. pipeline. The connection pipeline extends from Buchanan, located in the high-pressure ring that surrounds the city of Buenos Aires, which is part of tgs’s pipeline system, to Punta Lara. tgs’s ownership interest in such company is 49%, while Pan American Sur S.A. holds a 20.40%, Shell Argentina S.A. a 25.50% and Wintershall Dea Argentina S.A. the remaining 5.10%.

On December 29, 2021, Link paid a cash dividend for Ps. 181,984.

TGU:

TGU is a company incorporated in Uruguay. This company rendered operation and maintenance services to Gasoducto Cruz del Sur S.A. and its contract terminated in 2010. tgs holds 49% of its common stock and Pampa Energía holds the remaining 51%.

EGS (in liquidation):

In September 2003, EGS, a company registered in Argentina, was incorporated. The ownership is distributed between tgs (49%) and TGU (51%).

EGS owned a natural gas pipeline, which connects tgs’s main pipeline system in the Province of Santa Cruz with a delivery point on the border with Chile.

In October 2012, ENARGAS issued a resolution which authorizes EGS to transfer the connection pipeline and service offerings in operation to tgs. On November 13, 2013, the sale of all the fixed assets of EGS to tgs for an amount of US$ 350,000 was made, the existing natural gas transportation contracts were transferred and the procedures to dissolve the Company were initiated.

The Board of Directors Meeting held on January 13, 2016, approved to initiate the necessary steps for the dissolution of EGS. The Special Shareholders Meeting held on March 10, 2016 appointed EGS’ liquidator.

Joint Agreement

UT:

The Board of Directors of tgs approved the agreement to set up the UT together with SACDE. The objective of the UT is the assembly of pipes for the construction of the project of “Expansion of the System of Transportation and Distribution of Natural Gas” in the Province of Santa Fe, called by National Public Bid No. 452-0004-LPU17 by the MINEM (the “Work”).

On October 27, 2017, tgs - SACDE UT signed the corresponding work contract with the MINEM.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

The UT will remain in force until its purpose has been fulfilled, i.e., once the works involved in the Project have been completed and until the end of the guarantee period, set at 18 months from the provisional reception.

As a result of the situation of the economic context and COVID mentioned in Note 1, the UT sent a letter to Integración Energética Argentina S.A., a company currently part of the Ministry of Productive Development, requesting, among other issues, the reestablishment of the economic-financial equation, readjustment of the Work schedule, approval of cost redeterminations and price adjustments under the current legal regime. The parties are currently engaged in a detailed calculation of the items involved in the claim. In this regard, the UT has only carried out essential tasks, pending approval of a construction schedule appropriate to the actual execution of the works. The Company does not consider that there will be significant negative effects derived from this request to the Argentine Government.

On July 9, 2021, the UT and IEASA signed an order to restart the work related to the Project, through which the work schedule was readjusted and IEASA also assumed the commitment to manage and join efforts to guarantee the cash flow in order to avoid new effects on the economic-financial structure of the Works contract, which would give rise to new requests -by the UT- to recompose the economic-financial equation of the contract and the schedule of execution of the Work.

24. SUBSEQUENT EVENTS

The financial statements were authorized for issuance by the Board of Directors on April 25, 2023. There are no subsequent events between the closing date of year ended December 31, 2022, and the approval (issuance) of these consolidated financial statements, other than the ones already disclosed therein.

Natural gas transportation transitional tariff increase

On March 16, 2023, tgs’ Board of Directors approved the proposed addendum to the renegotiation transitory agreement (the “2023 transition agreement”) sent by ENARGAS. As of the date of issuance of these Financial Statements the 2023 transition agreement has not been ratified by the PEN.

The 2023 transition agreement has similar conditions to the 2022 Transition Agreement. The 2023 Transition Agreement includes:

-
A transitional tariff increase of 95% on the natural gas transportation tariff and the Access and Use Charge.

-
With prior authorization from the Ministry of Economy, tgs is allowed to distribute dividends and to directly or indirectly prepay financial and commercial debts contracted with shareholders. Previously prohibited by the 2022 Agreement.

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TRANSPORTADORA DE GAS DEL SUR S.A.

Notes to the Consolidated Financial Statements as of December 31, 2022 and comparative information

(Stated in thousands of pesos as described in Note 3 and 4.d., unless otherwise stated)

Annual Ordinary Shareholders’ Meeting

Allocation of 2022’s net income and retained earnings

On April 19, 2023, the Annual Ordinary Shareholders’ Meeting (the “2023 Shareholders´ Meeting”) approved the increase in the legal reserve of Ps. 1,967 million and the allocation of Ps. 185,004 million to the reserve for capital expenditures, acquisition of treasury shares and/or dividends (the “Reserve”). The Board of Directors can release the Reserve to tgs’ shareholders for such purposes.

It is noteworthy that the above-mentioned decisions made by the 2023 Shareholders’ Meeting were taken considering current CNV regulations (Resolution No. 777/2018) which states retained earnings have to be adjusted by inflation using the rates as of the month before the meeting was held. In case of 2022 Shareholders’ Meeting, tgs used the inflation rate as of March 31, 2023.

2017 Program

The 2023 Shareholders´ Meeting approved the increase from US$ 1,200 million to US$ 2,000 million of the 2017 Program. As of the date of issuance of this Consolidated Financial Statements the Company is preparing all the documents to be filed to the CNV in order to obtain the above-mentioned authorization and the extension of the 2017 Program which expires on January 3, 2024.

F-93

EX-2.6

EXHIBIT 2.6

DESCRIPTION OF SECURITIES REGISTERED UNDER SECTION 12 OF THE EXCHANGE ACT

Except as otherwise indicated or the context otherwise requires, capitalized terms used herein shall have the meaning ascribed to such terms in the report on Form 20-F of which this exhibit is a part.

General

As of the date of our annual report on Form 20-F of which this exhibit is a part, we have the following classes of securities registered or to be registered pursuant to Section 12 of the U.S. Securities Exchange Act of 1934, as amended (the "Exchange Act"):

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
American Depositary Shares ("ADS"), representing Class "B" Shares	TGS	New York Stock Exchange
Class "B" Shares, par value Ps.1.00 per share	n/a	New York Stock Exchange*

* Not for trading, but only in connection with the registration of American Depositary Shares related to the issuer's American Depositary Receipts ("ADRs" or "Receipts") program, pursuant to the requirements of the Securities and Exchange Commission.

As of March 31, 2023, we had 405,192,594 Class A Shares and 389,302,689 Class B Shares (including 87,441,287 Class B Shares underlying ADSs and 41,734,225 Class B Shares held in treasury). According to data provided by the Depositary, as of March 31, 2023, there were 17,488,257 ADSs outstanding. Such ADSs represented approximately 11.01% of the total number of issued and outstanding Class B Shares as of such date.

Citibank N.A. is the Depositary of our ADSs pursuant to the Deposit Agreement. Each ADS represents five Class B Shares. The ADSs are listed on the NYSE under the trading symbol "TGS." The ADSs began trading on the NYSE on November 1, 1994. The Buenos Aires Stock Market (Bolsas y Mercados Argentinos, or "BYMA") is the principal Argentine Market for trading the Class b shares.

The Depositary's office at which the ADSs are administered and its principal executive office are located at 388 Greenwich Street, New York, New York 10013, U.S.A.

Our corporate affairs are governed by our bylaws, the Law No. 19,550 (or the "General Companies Act") and Law No. 26,831 (the "Capital Markets Law"), which differ from the legal principles that would apply if we were incorporated in a jurisdiction in the United States or in other jurisdictions outside Argentina. In addition, as the provider of natural gas transportation services through the exclusive use of the southern natural gas transportation system in Argentina, certain of our corporate affairs are governed by our License and the Pliego de Bases y Condiciones para la Privatización de Gas del Estado S.E. (the "Pliego").

As a result of changes in the shareholding of our controlling company, CIESA, a shareholders' agreement was signed on August 29, 2005 (the "Shareholders' Agreement"). This agreement governs certain matters relating to shareholder participation in CIESA and in us. This agreement divides the CIESA shares into five classes that grant the shareholders different rights and obligations with respect to us and CIESA, mainly regarding the designation of the members of our Board of Directors and our Statutory Committee. See "Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders—Shareholders' Agreement" in our annual report on Form 20-F of which this exhibit is a part.

Exhibit 2.6 - 1

The following description of our Class B Shares and the ADSs is a summary of the material terms of our bylaws, the Deposit Agreement and applicable Argentine law in effect as of the date of our annual report on Form 20-F of which this exhibit is a part. Because it is a summary, it does not describe every aspect of our Class B Shares, our bylaws, the Deposit Agreement or Argentine law and may not contain all of the information that is important to you. References to provisions of our bylaws and the Deposit Agreement are qualified in their entirety by reference to the full bylaws and the Deposit Agreement, respectively. An English translation of our bylaws and the Deposit Agreement have been filed as an exhibits to our annual report on Form 20-F of which this exhibit is a part.

Description of Common Stock

We have three classes of common stock, the Class A Shares, the Class B Shares and the Class C Shares. The bylaws also state that the Class A Shares shall at all times account for a minimum of 51.0% of our total outstanding voting stock and that the Class B Shares together with the Class C Shares shall at all times account for the remainder 49.0% of our total outstanding voting stock. The ratio between Class A Shares and Class B Shares and Class C Shares existing as of the date when the respective issue was decided must be maintained.

Class A Shares may only be transferred prior approval of the Natural Gas Regulatory Agency (Ente Nacional Regulador del Gas) or any successor thereof. Class C shares shall be maintained under an Employee Stock Ownership Program (Programa de Propiedad Participada) as prescribed by Chapter III of Law No. 23,696. Class C shares, that have been fully paid up by their buyer, may be converted into Class B shares at the request of their holders upon expiration of a three-year term as from the date of our incorporation.

All shares shall be issued in book-entry form, of Ps.1.00 par value each and carrying One (1) vote each.

Shares are indivisible. In case of co-ownership, representation of such co-owned shares must be consolidated into one holder in order to exercise rights and comply with obligations. Any limitations and restrictions on the ownership and transfer of shares shall be recorded in the certificates of the depositary entity.

Preferred shares may be issued, granting the economic preferences specified in the bylaws, as determined by the shareholders' meeting that resolved the issue of such shares.

Other than as described herein, holders of the Series A shares and the Series B shares have the same rights and obligations. As of the date of the annual report on Form 20-F of which this exhibit is a part there are no preferred shares or any privilege.

Increases in Capital Stock

The capital stock and its evolution shall be recorded in our balance sheets as it may result from the capital increases registered with the Public Registry of Commerce. Our capital stock may be increased by decision of the shareholders' meeting without any limitation and without the need to amend the bylaws.

Exhibit 2.6 - 2

Creation of ADSs — Deposit, Withdrawal and Cancellation

Class B Shares or evidence of rights to receive Class B Shares may be deposited by delivery thereof to the Custodian (as defined in the Deposit Agreement), accompanied by any appropriate instrument or instruments of transfer, or endorsement, in form satisfactory to the custodian, together with all such certifications as may be required by the Depositary or the Custodian in accordance with the provisions of the Deposit Agreement, and, if the Depositary requires, together with a written order directing the Depositary to execute and deliver to, or upon the written order of, the person or persons stated in such order, Receipts for the number of ADSs representing such deposit. No Class B Share shall be accepted for deposit unless accompanied by evidence satisfactory to the Depositary that any necessary approval has been granted by any governmental body in Argentina which is then performing the function of the regulation of currency exchange.

Upon surrender at the Corporate Trust Office of the Depositary of a Receipt for the purpose of withdrawal of the deposited securities represented by the ADSs evidenced by such Receipt, and upon payment of the fee of the Depositary for the surrender of Receipts and payment of all taxes and governmental charges payable in connection with such surrender and withdrawal of the deposited securities, and subject to the terms and conditions of the Deposit Agreement, the owner of such Receipt shall be entitled to delivery, to him or upon his order, of the amount of deposited securities at the time represented by the ADSs evidenced by such Receipt.

As a condition precedent to the execution and delivery, registration of transfer, split-up, combination or surrender of any Receipt or withdrawal of any deposited securities, the Depositary, Custodian or registrar may require payment from the depositor of Class B Shares or the presenter of the Receipt of a sum sufficient to reimburse it for any tax or other governmental charge and any stock transfer or registration fee with respect thereto (including any such tax or charge and fee with respect to Class B Shares being deposited or withdrawn) and payment of any applicable fees.

All Receipts surrendered to the Depositary shall be canceled by the Depositary. Canceled Receipts shall not be entitled to any benefits under the Deposit Agreement or be valid or enforceable for any purpose. The Depositary is authorized to destroy Receipts so canceled.

Dividends and Other Distributions

Under our bylaws, all Class A, Class B and Class C shares rank equally with respect to the payment of dividends. All shares outstanding as of a particular record date share equally in the dividend being paid, except that shares issued during the period to which a dividend relates may be entitled only to a partial dividend with respect to such period if the shareholders' meeting that approved the issuance so resolved. No provision of our bylaws or of the General Companies Act gives rise to future special dividends only to certain shareholders.

The amount and payment of dividends are determined by majority vote of our shareholders voting as a single class, generally, but not necessarily, on the recommendation of the Board of Directors. In addition, under the General Companies Act, our Board of Directors has the right to declare dividends subject to further approval of the shareholders' meeting.

In our Board of Directors meeting held on December 18, 2019, the Board approved a written dividend policy. This policy provides that in making its evaluation, our Board of Directors should consider our financial results, our liquidity, our future financing needs and other information, including economic and financial projections for both our and the economy as a whole. Each year, our Board evaluates whether to submit a distribution proposal to the shareholders' meeting. Nevertheless, there are a number of restrictions that limit our ability to distribute dividends. For additional information regarding dividend payments, see "Item 8. Financial Information—A. Consolidated Statements and Other Financial Information—Dividend Distribution Policy" in our annual report on Form 20-F of which this exhibit is a part.

Exhibit 2.6 - 3

Under applicable CNV regulations and our bylaws, cash dividends must be paid to shareholders within 30 days from the shareholders' meeting approving such dividends. In cases where the shareholders meeting delegates the authority for the distribution of dividends to the Board of Directors, the payment of dividends has been usually resolved within 30 days from the relevant Board of Directors' resolution. In the case of payment of stock dividends, or payment of both stock and cash dividends, both shares and cash are required to be available within three months of the receipt of notice of the authorization of the CNV for the public offering of the shares arising from such dividends. In accordance with the Argentine Civil and Commercial Code, the statute of limitations to the right of any shareholder to receive dividends declared by the shareholders' meeting is five years from the date on which it has been made available to the shareholder. However, according to our bylaws, dividends in cash approved by the shareholders' meeting which remain unclaimed for three (3) years calculated as from the date established for payment thereof shall be forfeited to our benefit. In this case, such unclaimed dividends shall be allocated to a special reserve to be used as the shareholders' meeting may decide.

Owners of ADSs are entitled to receive any dividends payable with respect to the underlying Class B shares.

Cash dividends may be paid to the Depositary in U.S. dollars or other currency, as long as the applicable laws and regulations allow it. The Deposit Agreement provides that the Depositary shall convert cash dividends received by the Depositary in foreign currency to dollars, to the extent that, in the judgment of the Depositary, such conversion may be made on a practicable basis, and, after deduction or upon payment of the fees and expenses of the Depositary, and withholding of applicable taxes, shall make payment to the holders of ADSs in U.S. dollars.

Each holder of the ADRs is entitled to receive dividends in the form of shares in proportion to the number of ADSs held by such holder after deduction or upon payment of the fees and expenses of the Depositary, and withholding of applicable taxes.

Amount Available for Distribution

Under the General Companies Act, dividends of a listed company may be lawfully paid only out of liquid and realized profits reflected in the annual audited financial statements of the company prepared in accordance with accounting rules prevailing in Argentina and CNV regulations and approved by a shareholders' meeting. The Board of Directors of a listed company may declare interim or provisional dividends, in cash, or based on special or quarterly financial statements with the report of the external auditor and the Supervisory Committee, in which case the members of the Board, the members of the Statutory Supervisory Commission (Comisión Fiscalizadora) and of the Supervisory Committee are jointly and severally liable for the repayment of such dividends if retained earnings at the close of the fiscal year in which such dividends were paid would not have been sufficient to permit the applicable distribution.

Every year, our Board of Directors submits to the annual ordinary shareholders' meeting for approval the financial statements for the preceding fiscal year, together with reports thereon by the Supervisory Commission and the external auditor. Within four months of the end of each fiscal year, an ordinary shareholders' meeting must be held to discuss the annual financial statements and determine the allocation of our net income for such year, if any.

Exhibit 2.6 - 4

Pursuant to the General Companies Act and the CNV Rules, we are required to allocate a legal reserve ("Legal Reserve") equal to at least 5% of each year's net income (as long as there are no losses for prior fiscal years pending to be absorbed) until the aggregate amount of such Legal Reserve equals 20% of the sum of (i) "common stock nominal value" plus (ii) "inflation adjustment to common stock," as shown in our consolidated statement of changes in equity. If there are any losses pending to be absorbed from prior fiscal years, such 5% should be calculated on any excess of the net income over such losses, if any. Dividends may not be paid if the Legal Reserve has been impaired, nor until it has been fully replenished. The Legal Reserve is not available for distribution as a dividend.

Pursuant to our bylaws, liquid and realized profits shall be allocated in the following manner: first, to the Legal Reserve; second, to pay the remuneration of the members of the Board of Directors and Statutory Supervisory Commission; third, to pay cumulative dividends in arrears and current dividends with respect to preferred shares, if any; fourth, an amount equal to 0.25% of the net income for the year will be allocated to pay the statutory employee profit-sharing; and fifth, the balance of the retained earnings for the year may be retained as a voluntary reserve or distributed as dividends on our shares, as determined at the general annual shareholders' meeting.

Share Repurchases

If approved by our shareholders at a general shareholders' meeting or by our Board of Directors, we may purchase our outstanding shares. The economic and voting rights corresponding to repurchased shares cannot be exercised during the period the shares are owned by us and the shares will be deemed outstanding for purposes of calculating any quorum or vote at any shareholders' meeting. See "Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders—Repurchase of Shares" in our annual report on Form 20-F of which this exhibit is a part.

Voting of the Underlying Class B Shares

Voting Power

Under our bylaws, each Class A, Class B and Class C share entitles the holder thereof to one vote at each shareholders' meeting. If preferred shares are issued, they shall not carry any votes, except in certain specific cases as set forth in our bylaws and the resolutions of the shareholders meeting approving the issuance of such shares.

Whenever the shareholders' meeting must adopt resolutions affecting the rights of one Class of shares, the consent or ratification of such Class shall be given at a Class meeting governed by the rules established in these bylaws for ordinary shareholders' meetings.

Notice of Meetings to Holders of ADSs

Upon receipt of notice of any meeting of holders of Class B Shares, if requested in writing by us the Depositary shall, as soon as practicable thereafter, mail to the owners of ADSs a notice, the form of which notice shall be approved by us, which shall contain (a) such information as is contained in such notice of meeting received by the Depositary from us, (b) a statement that the owners as of the close of business on a specified record date will be entitled, subject to any applicable provision of the laws of Argentina and of our bylaws, to instruct the Depositary as to the exercise of the voting rights, if any, pertaining to the amount of Class B Shares or other deposited securities represented by their respective ADSs and (c) a statement as to the manner in which such instructions may be given, including an express indication that such instructions may be given or deemed given in accordance with this paragraph if no instruction is received, to the Depositary to give a discretionary proxy to a person designated by us.

Exhibit 2.6 - 5

Vote Casting by ADS Holders

Upon the written request of an owner on such record date, received on or before the date established by the Depositary for such purpose, (the "Instruction Date") the Depositary shall endeavor, in so far as practicable and permitted under applicable law and our bylaws, to vote or cause to be voted the amount of Class B Shares or other deposited securities represented by the ADSs evidenced by such Receipt in accordance with the instructions set forth in such request. The Depositary shall not vote or attempt to exercise the right to vote that attaches to the Class B Shares or other deposited securities, other than in accordance with such instructions or deemed instructions. If no instructions are received by the Depositary from any owner with respect to any of the Class B Shares or other deposited securities represented by the ADSs evidenced by such owner's Receipts on or before the Instruction Date, the Depositary shall deem such owner to have instructed the Depositary to give a discretionary proxy to a person designated by us with respect to such deposited securities and the Depositary shall give a discretionary proxy to a person designated by us to vote such deposited securities, provided that no instruction shall be given with respect to any matter as to which we inform the Depositary that we do not wish such proxy given.

There can be no assurance that owners generally or any owner in particular will receive the notice of a meeting sufficiently prior to the Instruction Date to ensure that the Depositary will vote the Class B Shares or deposited securities in accordance with the provisions set forth in the preceding paragraph.

In addition, the Depositary will, unless otherwise requested by us, insofar as permitted under applicable law and our bylaws, deposit substantially all of the Class B Shares represented by ADSs then outstanding for the purpose of establishing a quorum at any meeting of shareholders, whether or not voting instructions with respect to such Class B Shares have been received.

Notwithstanding the foregoing, the Depositary will not vote the Class B Shares or other deposited securities in accordance with the Deposit Agreement unless we have provided to the Depositary an opinion of Argentine counsel (which may be the general counsel of the issuer), which states that such action is not in contravention of Argentine law or our bylaws.

Foreign Shareholders

In addition, under the General Companies Act, foreign companies that own shares in an Argentine corporation are required to register with the Superintendency of Corporations (Inspección General de Justicia or the "IGJ") in order to exercise certain shareholder rights. Voting rights in a shareholders' meeting can be exercised through duly instituted agents, as is regulated by the Capital Markets Law. Direct owners of Class B Shares (rather than in the form of ADSs) that are not Argentine companies and that fail to register with the IGJ, may have limited ability to exercise their rights as a holder of our Class B Shares.

Exhibit 2.6 - 6

Preemptive Rights

Class A, Class B and Class C shareholders shall be entitled to preemptive rights in the subscription for new shares, within their same Class and in proportion of their respective holdings, and they shall be entitled to additional preemptive rights pursuant to Article 194 et seq. of the General Companies Act. Should any balance of unsubscribed for shares remain, such shares may be offered to third parties. The issue of common shares pertaining to future capital increases must abide by the following proportions: 51% of the aggregate of Class A shares and 49% of Class B and C shares, these two classes of shares must keep the same ratio existing as of the date when the respective issue was decided. If preferred shares are issued, the holders of common shares shall be entitled to preemptive rights in the subscription of preferred shares, on a pro rata basis of their respective holdings and without any class distinction.

Holders of ADSs may be restricted in their ability to exercise preemptive rights if a registration statement under the Securities Act relating thereto has not been filed or is not effective. Preemptive rights are exercisable during the 30 days following the last publication of notice informing shareholders of their right to exercise such preemptive rights in the Official Gazette and in an Argentine newspaper of wide circulation. Pursuant to the General Companies Act, if authorized by a special shareholders' meeting, companies authorized to make public offering of their securities, such as tgs, may shorten the period during which preemptive rights may be exercised from 30 to 10 days following the publication of notice of the offering to the shareholders to exercise preemptive rights in the Official Gazette and a newspaper of wide circulation in Argentina.

The term for exercise of accretion rights is the same as that fixed for exercising preemptive rights

Amendment and Termination

Amendment of Deposit Agreement

The form of the Receipts and any provisions of the Deposit Agreement may at any time and from time to time be amended by agreement between us and the Depositary without the consent of owners and beneficial owners in any respect which they may deem necessary or desirable. Any amendment which shall impose or increase any fees or charges (other than taxes and other governmental charges, registration fees, cable, telex or facsimile transmission costs, delivery costs or other such expenses), or which shall otherwise prejudice any substantial existing right of owners, shall, however, not become effective as to outstanding Receipts until the expiration of 30 days after notice of such amendment shall have been given to the owners of outstanding Receipts. Every owner at the time any amendment so becomes effective shall be deemed, by continuing to hold such Receipt, to consent and agree to such amendment and to be bound by the Deposit Agreement as amended thereby. In no event shall any amendment impair the right of the owner of any Receipt to surrender such Receipt and receive therefor the deposited securities represented thereby, except in order to comply with mandatory provisions of applicable law.

Exhibit 2.6 - 7

Termination of Deposit Agreement

The Depositary shall at any time at our direction terminate the Deposit Agreement by mailing notice of such termination to the owners of all Receipts then outstanding at least 30 days prior to the date fixed in such notice for such termination. The Depositary may likewise terminate the Deposit Agreement by mailing notice of such termination to us and the owners of all Receipts then outstanding if at any time ninety days shall have expired after the Depositary shall have delivered to us a written notice of its election to resign and a successor depositary shall not have been appointed and accepted its appointment. On and after the date of termination, the owner of a Receipt will, upon (a) surrender of such Receipt at the Corporate Trust Office of the Depositary, (b) payment of the fee of the Depositary for the surrender of Receipts, and (c) payment of any applicable taxes or governmental charges, be entitled to delivery, to him or upon his order, of the amount of deposited securities represented by the American Depositary Shares evidenced by such Receipt. If any Receipts shall remain outstanding after the date of termination, the Depositary thereafter shall discontinue the registration of transfers of Receipts, shall suspend the distribution of dividends to the owners thereof, and shall not give any further notices or perform any further acts under the Deposit Agreement, except that the Depositary shall continue to collect dividends and other distributions pertaining to deposited securities, shall sell rights and other property as provided in the Deposit Agreement, and shall continue to deliver deposited securities, together with any dividends or other distributions received with respect thereto and the net proceeds of the sale of any rights or other property, in exchange for Receipts surrendered to the Depositary (after deducting, in each case, the fee of the Depositary for the surrender of a Receipt, any expenses for the account of the owner of such Receipt in accordance with the terms and conditions of the Deposit Agreement, and any applicable taxes or governmental charges). At any time after the expiration of one year from the date of termination, the Depositary may sell the Class B Shares or other deposited securities then held thereunder and may thereafter hold uninvested the net proceeds of any such sale, together with any other cash then held by it under the Deposit Agreement, unsegregated and without liability for interest, for the pro rata benefit of the owners of Receipts which have not theretofore been surrendered, such owners thereupon becoming general creditors of the Depositary with respect to such net proceeds. After making such sale, the Depositary shall be discharged from all obligations under the Deposit Agreement, except to account for such net proceeds and other cash (after deducting, in each case, the fee of the Depositary for the surrender of a Receipt, any expenses for the account of the owner of such Receipt in accordance with the terms and conditions of the Deposit Agreement, and any applicable taxes or governmental charges).

Limitations on Obligations and Liability

The Deposit Agreement expressly limits our obligations and the obligations of the Depositary. It also limits our liability and the liability of the Depositary. We and the depositary:

a) are not liable to any owner or beneficial owner of any Receipt, if by reason of any provision of any present or future law or regulation of the United States or any other country, or of any governmental or regulatory authority or stock exchange, or by reason of any provision, present or future, of our bylaws, or by reason of any provision of any securities issued or distributed by us, or any offering or distribution thereof, or by reason of any act of God or war or terrorism or other circumstances beyond our control, we or any of our respective directors, employees, agents or affiliates shall be prevented, delayed or forbidden from, or be subject to any civil or criminal penalty on account of, doing or performing any act or thing which by the terms of the Deposit Agreement or the deposited securities it is provided shall be done or performed, nor shall we or any of our respective directors, employees, agents or affiliates incur any liability to any owner or beneficial owner of any Receipt by reason of any non-performance or delay, caused as aforesaid, in the performance of any act or thing which by the terms of the Deposit Agreement it is provided shall or may be done or performed, or by reason of any exercise of, or failure to exercise, any discretion provided for in the Deposit Agreement;

b) do not assume any obligation or liability under the Deposit Agreement or the Receipts to owners, beneficial owners of Receipts or other persons, except that we agree to perform our obligations specifically set forth in the Deposit Agreement without negligence or bad faith;

c) shall not be under any obligation to appear in, prosecute or defend any action, suit or other proceeding in respect of any deposited securities or in respect of the Receipts, which in its opinion may involve it in expense or liability, unless indemnity satisfactory to it against all expense and liability shall be furnished as often as may be required, and the custodian shall not be under any obligation whatsoever with respect to such proceedings, the responsibility of the custodian being solely to the Depositary;

Exhibit 2.6 - 8

d) shall not be liable for any action or nonaction by us in reliance upon the advice of or information from legal counsel, accountants, any person presenting Class B Shares for deposit, any owner, beneficial owner or any other person believed by it in good faith to be competent to give such advice or information;

e) the Depositary shall not be liable for any acts or omissions made by a successor depositary whether in connection with a previous act or omission of the Depositary or in connection with any matter arising wholly after the removal or resignation of the Depositary, provided that in connection with the issue out of which such potential liability arises the Depositary performed its obligations without negligence or bad faith while it acted as Depositary;

f) the Depositary shall not be responsible for any failure to carry out any instructions to vote any of the deposited securities, or for the manner in which any such vote is cast or the effect of any such vote, provided that any such action or nonaction is in good faith.

In the deposit agreement, we and the depositary agree to indemnify each other under certain circumstances.

Reports

The Depositary shall make available for inspection by owners at its Corporate Trust Office and at the principal office of each custodian copies of any notices, reports or communications, including any proxy soliciting material, received from us which are both (a) received by the Depositary and the custodian or the nominees of both as the holder of the deposited securities and (b) made generally available to the holders of such deposited securities by us. The Depositary shall also, upon written request, send to the owners copies of such reports furnished by us pursuant to the Deposit Agreement. Any such reports and communications, including any such proxy soliciting material, furnished to the Depositary shall be furnished in English.

Maintenance of Office and Transfer Books by the Registrar

Until termination of the Deposit Agreement in accordance with its terms, the Registrar shall maintain in the Borough of Manhattan, the City of New York, an office and facilities for the issuance and delivery of ADSs, the acceptance for surrender of ADS(s) for the purpose of withdrawal of Class B Shares, the registration of issuances, cancellations, transfers, combinations and split-ups of ADS(s) and, if applicable, to countersign ADRs evidencing the ADSs so issued, transferred, combined or split-up, in each case in accordance with the provisions of the Deposit Agreement.

The Registrar shall keep books for the registration of ADSs which at all reasonable times shall be open for inspection by us and by the holders of such ADSs, provided that such inspection shall not be, to the Registrar's knowledge, for the purpose of communicating with holders of such ADSs in the interest of a business or object other than our business or other than a matter related to the Deposit Agreement or the ADSs.

Bylaws

At a meeting on May 27, 2014, our shareholders approved an amendment to our bylaws to adapt such bylaws to the Capital Markets Law, and to other regulatory requirements of CNV. In addition, at such meeting, our Board of Directors suggested certain other amendments to adopt a more flexible corporate management and consolidate the effective bylaws of tgs in a single document. Such bylaws have been included as Exhibit 1.2 to our annual report on form 20-F for the year ended December 31, 2014 filed with the SEC.

Exhibit 2.6 - 9

Call for Shareholders' Meetings

Pursuant to our bylaws, ordinary and/or extraordinary shareholders meetings shall be convened by the Board of Directors or the Statutory Auditor (Síndico) in the cases provided by law, or whenever any one of them deem it necessary or upon request of shareholders of any Class holding no less than 5% of the capital stock. In the latter case the notice shall specify the items of business to be transacted and the Board of Directors or the Statutory Auditor (Síndico) shall convene the shareholders' meeting to be held within a maximum 40-day term as from the date of receipt of the notice. If the Board of Directors or the Statutory Auditor (Síndico) would fail to do so, the shareholders' meeting may be convened by the supervisory agency or the court.

Notices of Meetings

Shareholders' meetings shall be convened by notices made in advance within a minimum 20-day period and a maximum 45-day period published during five days in the Official Bulletin and in one leading newspaper of general circulation in Argentina. The notice must specify the nature of the shareholders' meeting and the date, time and place of the meeting as well as the Agenda of Items of Business. Shareholders meetings in second call due to the failure of the first one must be held within the following 30 days, and the publications will be made for 3 days with at least 8 in advance. The ordinary shareholders meeting may be convened simultaneously on the first and second call. If the Meeting on second call is called to be held on the same day as the first call, it must be done with an interval of no less than one hour. If the legal constitution of Meeting had failed due to lack of the necessary assistance and, if in the case of the ordinary shareholders meeting it had not been summoned simultaneously in the first and second call, it must be called again within the following 30 days.

Quorum and Voting Requirements

Ordinary shareholders' meetings shall be validly held on first call with the attendance of shareholders representing a majority of voting shares, and on second call with the attendance of any number of voting shares present. Action shall be adopted in both cases by an absolute majority of voting shares present that may be casted on the respective decision.

Extraordinary shareholders' meetings shall be validly held on first call with the attendance of shareholders representing 61% of the voting shares and on second call with the attendance of whatever number of voting shares. Action in both cases shall be taken with the absolute majority of votes present that may be cast in the respective decision, except for the case provided under the last paragraph of Article 244 of the General Companies Act and Article 18 of the bylaws.

Amendments to Bylaws

For a minimum period of two years calculated as from the date of transfer of the aggregate Class A shares to the current owner of the Class A Shares as winning bidder in the International Public Tender for the privatization of Gas del Estado Sociedad del Estado or until the ANSES (as defined below) has transferred its aggregate Class B shares, whatever occurs first, any amendment to our bylaws and any capital increase requires the affirmative vote of the shares of such Class held by the ANSES.  Upon expiration of such two-year term or upon occurrence of such event, amendment to certain provisions of our bylaws shall require the prior authorization of the Natural Gas Regulatory Agency or any successor thereof.

Exhibit 2.6 - 10

Foreign Investment Legislation

Under the Argentine Foreign Investment Law, as amended, and its implementing regulations (together, referred to as the "Foreign Investment Legislation"), the purchase of shares of an Argentine corporation by an individual or legal entity domiciled abroad or by an Argentine company of "foreign capital" (as defined in the Foreign Investment Legislation) constitutes foreign investment. Currently, foreign investment in industries other than broadcasting, purchase land located in frontier and other security areas by foreigners and limits on the ownership of rural land by foreign individuals or legal entities according to Law 26,737, is not restricted, and no prior approval is required to make foreign investments.

Reporting Requirements

Pursuant to the regulations of CNV, any person that directly or indirectly, or any group of persons acting in concerted form, by any means and with a certain purpose:

a) acquire or dispose of shares or securities convertible into shares, or acquire call or put options over them;

b) alter the integration or configuration of its direct or indirect interest over the capital stock of an issuer;

c) convert notes (obligaciones negociables) into shares;

d) exercise the put or call options of the securities referred to in a); or

e) change their purpose regarding their interest in an issuer at the time of occurrence of any of the abovementioned events;

is required to inform CNV and BYMA of such circumstances, immediately after executing the acquisition, disposal, alteration of the integration or configuration of the interest, conversion into shares, and/or exercise of the calls or put options referred to above, or after the occurrence of the change in the purpose referred to above.

In any case, the information shall be submitted only as long as the acquisitions involved and/or facts referred to above grant 5% or more of the voting rights that can be exercised in our shareholders´ meetings.

Similar information is required to be submitted to CNV and BYMA in the event of changes over the interests previously informed, until becoming a controlling shareholder in which case the regulations applicable to such person shall become applicable.

Board of Directors

See "Item 6. Directors, Senior Management and Employees—A. Directors and Senior Management" for a description of the provisions relating to the integration of our Board of directors and the rights of the different Classes of shares or controlling groups with respect thereto.

Exhibit 2.6 - 11

Fees and Charges

An ADS holder is required to pay the following service fees to the Depositary:

Service	Rate	By Whom Paid
(1) Issuance of ADSs (e.g., an issuance upon a deposit of Shares, upon a change in the ADS(s)- to-Share(s) ratio, or for any other reason), excluding issuances as a result of distributions described in paragraph (4) below.	Up to US$5.00 per 100 ADSs (or fraction thereof) issued.	Person receiving ADSs.
(2) Cancellation of ADSs (e.g., a cancellation of ADSs for delivery of deposited Shares, upon a change in the ADS(s)-to-Share(s) ratio, or for any other reason).	Up to US$5.00 per 100 ADSs (or fraction thereof) canceled.	Person whose ADSs are being canceled.
(3) Distribution of cash dividends or other cash distributions (e.g., upon a sale of rights and other entitlements).	Up to US$5.00 per 100 ADSs (or fraction thereof) held.	Person to whom the distribution is made.
(4)Distribution of ADSs pursuant to (i) stock dividends or other free stock distributions, or (ii) an exercise of rights to purchase additional ADSs.	Up to US$5.00 per 100 ADSs (or fraction thereof) held.	Person to whom the distribution is made.
(5) Distribution of securities other than ADSs or rights to purchase additional ADSs (e.g., spin- off shares).	Up to US$5.00 per 100 ADSs (or fraction thereof) held.	Person to whom the distribution is made.
(6) ADS Services.	Up to US$5.00 per 100 ADSs (or fraction thereof) held on the applicable record date(s) established by the Depositary.	Person holding ADSs on the applicable record date(s) established by the Depositary.

We, holders, beneficial owners, persons receiving ADSs upon issuance and persons whose ADSs are being canceled shall be responsible for the following ADS charges under the terms of the Deposit Agreement:

a)          taxes (including applicable interest and penalties) and other governmental charges;

b)        such registration fees as may from time to time be in effect for the registration of Class B Shares or other deposited securities on the share register and applicable to transfers of Shares or other Deposited Securities to or from the name of the Custodian, the Depositary or any nominees upon the making of deposits and withdrawals, respectively;

c)          such cable, telex and facsimile transmission and delivery expenses as are expressly provided in the Deposit Agreement to be at the expense of the person depositing Shares or withdrawing Class B Shares or other deposited securities or of the holders and beneficial owners of ADSs;

d)          the expenses and charges incurred by the Depositary in the conversion of foreign currency;

Exhibit 2.6 - 12

e)         such fees and expenses as are incurred by the Depositary in connection with compliance with exchange control regulations and other regulatory requirements applicable to Shares, Deposited Securities, ADSs and ADRs; and

f)         the fees and expenses incurred by the Depositary, the Custodian, or any nominee in connection with the servicing or delivery of Deposited Property.

Taxes

Holders of ADSs will be responsible for the taxes and other governmental charges payable on the ADSs and the securities represented by the ADSs.  We, the ADS depositary and the custodian may deduct from any distribution the taxes and governmental charges payable by holders and may sell any and all property on deposit to pay the taxes and governmental charges payable by holders.  holders of ADSs will be liable for any deficiency if the sale proceeds do not cover the taxes that are due.

Shareholding Interest of ANSES

In 2008, the Government absorbed and replaced the former private pension system with a public "pay as you go" pension system. As a result, all resources administered by the private pension funds, including significant equity interests in a wide range of listed companies, were transferred to a separate fund (Fondo de Garantía de Sustentabilidad or "FGS") to be managed by the National Social Security Administration Service (Administración Nacional de la Seguridad Social, or "ANSES"). ANSES is entitled to designate government representatives to the boards of directors of these companies.

According to applicable regulations, any transfer or other action that limits, alters, cancels or modifies the destination, ownership, possession or nature of the shares held by the FGS which results in a decrease of the FGS's holdings in a manner inconsistent with applicable law, shall not be conducted without prior express authorization of the Argentine Congress, subject to certain exceptions. See "Item 7. Major Shareholders and Related Party Transactions—A. Major Shareholders" in our annual report on Form 20-F of which this exhibit is a part.

 

Exhibit 2.6 - 13

EX-8.1

EXHIBIT 8.1

SUBSIDIARIES

The following are our subsidiaries:

Company Name	Country of incorporation	Proportion of Ownership Interest
Telcosur S.A.	Argentina	99.98%
CTG Energía S.A.U.	Argentina	100.00%
TGSLatam Energía S.A.	Bolivia	80.00%

Exhibit 8.1

EX-12.1

EXHIBIT 12.1

CERTIFICATION

I, Oscar Sardi, certify that:

1. I have reviewed this annual report on Form 20-F for the year ended December 31, 2022, of Transportadora de Gas del Sur S.A.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the company as of, and for, the periods presented in this report;

4. The company's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)), for the company and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the company, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with IFRS as issued by the IASB;

c) Evaluated the effectiveness of the company's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the company's internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company's internal control over financial reporting; and

5. The company's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the company's auditors and the audit committee of the company's board of directors (or persons performing the equivalent function):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the company's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the company's internal control over financial reporting.

Date: April 25, 2023
	/s/ Oscar José Sardi
	Oscar José Sardi
	Chief Executive Officer

Exhibit 12.1

EX-12.2

EXHIBIT 12.2

Certification

I, Alejandro M. Basso, certify that:

1. I have reviewed this annual report on Form 20-F for the year ended December 31, 2022, of Transportadora de Gas del Sur S.A.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the company as of, and for, the periods presented in this report;

4. The company's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)), for the company and have:

a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the company, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with IFRS as issued by the IASB;

c) Evaluated the effectiveness of the company's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d) Disclosed in this report any change in the company's internal control over financial reporting that occurred during the period covered by the annual report that has materially affected, or is reasonably likely to materially affect, the company's internal control over financial reporting.

5. The company's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the company's auditors and the audit committee of the company's board of directors (or persons performing the equivalent function):

a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the company's ability to record, process, summarize and report financial information; and

b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the company's internal control over financial reporting.

Date: April 25, 2023
	/s/ Alejandro M. Basso
	Alejandro M. Basso
	Chief Financial Officer and Services Vice President

Exhibit 12.2

EX-13.1

EXHIBIT 13.1

CERTIFICATION

Pursuant to section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of section 1350, chapter 63 of title 18, United States Code), the undersigned officer of Transportadora de Gas del Sur S.A. (the "Company"), hereby certifies, to such officer's knowledge, that:

The Company's annual report on Form 20-F for the year ended December 31, 2022 (the "Report") fully complies with the requirements of section 13(a) or 15(d) of the U.S. Securities Exchange Act of 1934, as amended, and all information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: April 25, 2023
	/s/ Oscar Sardi
	Oscar Sardi
	Chief Executive Officer

Exhibit 13.1

EX-13.2

EXHIBIT 13.2

CERTIFICATION

Pursuant to section 906 of the Sarbanes-Oxley Act of 2002 (subsections (a) and (b) of section 1350, chapter 63 of title 18, United States Code), the undersigned officer of Transportadora de Gas del Sur S.A. (the "Company"), hereby certifies, to such officer's knowledge, that:

The Company's annual report on Form 20-F for the year ended December 31, 2022 (the "Report") fully complies with the requirements of section 13(a) or 15(d) of the U.S. Securities Exchange Act of 1934, as amended, and all information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Dated: April 25, 2023
	/s/ Alejandro M. Basso
	Alejandro M. Basso
	Chief Financial Officer and Services Vice President

Exhibit 13.2

XML

Document and Entity Information	12 Months Ended
	Dec. 31, 2022 shares
Entity Listings [Line Items]
Document Type	20-F
Amendment Flag	false
Document Registration Statement	false
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY
Document Transition Report	false
Document Shell Company Report	false
Entity File Number	001-13396
Entity Registrant Name	GAS TRANSPORTER OF THE SOUTH INC.
Entity Central Index Key	0000931427
Entity Incorporation, State or Country Code	C1
Entity Address, Address Line One	Don Bosco 3672
Entity Address, Address Line Two	5th Floor
Entity Address, Postal Zip Code	1206
Entity Address, City or Town	Buenos Aires
Entity Address, Country	AR
Entity Common Stock, Shares Outstanding	752,761,058
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Document Accounting Standard	International Financial Reporting Standards
Entity Shell Company	false
Auditor Firm ID	1349
Auditor Name	Price Waterhouse & Co. S.R.L.
Auditor Location	Buenos Aires, Argentina
Pistrelli, Henry Martin y Asociados S.R.L [Member]
Entity Listings [Line Items]
Auditor Firm ID	1449
Auditor Name	Pistrelli, Henry Martin y Asociados S.R.L.
Auditor Location	Buenos Aires, Argentina
Business Contact [Member]
Entity Listings [Line Items]
Entity Address, Address Line One	Don Bosco 3672
Entity Address, Address Line Two	5th Floor
Entity Address, Postal Zip Code	1206
Entity Address, City or Town	Buenos Aires
Entity Address, Country	AR
Contact Personnel Name	Leandro Pérez Castaño
City Area Code	54-11
Local Phone Number	4865-9077
Contact Personnel Email Address	inversores@tgs.com.ar
Class "A" [Member]
Entity Listings [Line Items]
Title of 12(b) Security	American Depositary Shares (“ADS”), representing Class “B” Shares
Trading Symbol	TGS
Security Exchange Name	NYSE
Entity Common Stock, Shares Outstanding	405,192,594
Class "B" [Member]
Entity Listings [Line Items]
Title of 12(b) Security	Class “B” Shares, par value Ps.1.00 per share
Trading Symbol	n/a
Security Exchange Name	NYSE
Entity Common Stock, Shares Outstanding	347,568,464

XML

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME [Abstract]
Revenues		$ 164,524,789	$ 173,319,821	$ 164,275,443
Net cost of sales		(96,041,564)	(92,843,404)	(81,049,791)
Gross profit		68,483,225	80,476,417	83,225,652
Administrative expenses		(5,754,433)	(4,996,067)	(4,947,813)
Selling expenses		(10,203,597)	(9,339,564)	(8,725,879)
Other operating results		(76,498)	250,925	293,522
Impairment of PPE		0	0	(9,156,072)
Operating profit		52,448,697	66,391,711	60,689,410
Net financial results
Financial income		29,776,707	13,386,552	16,216,663
Financial expenses		(58,904,450)	(32,942,739)	(53,495,791)
Other financial results		22,199,580	395,150	(19,919,477)
Gain on net monetary position		3,768,283	18,311,140	19,058,813
Total net financial results		(3,159,880)	(849,897)	(38,139,792)
Share of profit from associates		90,138	41,347	62,657
Net income before income tax		49,378,955	65,583,161	22,612,275
Income tax expense		(17,061,153)	(24,810,849)	(12,950,061)
Total comprehensive income for the year		32,317,802	40,772,312	9,662,214
Total comprehensive income attributable to:
Owners of the Company		32,317,790	40,772,306	9,662,187
Non-controlling interests		$ 12	$ 6	$ 27
Total comprehensive income per share attributable to owners of the Company:
Weighted average of outstanding ordinary shares (in shares)	[1],[2]	752,761,058	752,761,058	762,371,755
Basic earnings per share (in pesos per share)		$ 42.93	$ 54.16	$ 12.68
Diluted earnings per share (in pesos per share)		$ 42.93	$ 54.16	$ 12.68

[1] The weighted average number of shares considers the effect of the weighted average of the changes originated in the transactions with the treasury shares made during the year.

[2] The weighted average of the number of shares considers the effect of the weighted average of the changes originated in the transactions with treasury shares made during the year.

XML

CONSOLIDATED STATEMENTS OF FINANCIAL POSITION - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Non-current assets
Property, plant and equipment	$ 294,479,596	$ 292,534,643
Investments in associates	154,502	64,371
Financial assets measured at amortised cost	40,162,283	43,720,399
Deferred income tax asset	27,410	46,277
Other receivables	14,899	17,249
Total non-current assets	334,838,690	336,382,939
Current assets
Other receivables	16,176,638	11,642,263
Inventories	1,833,545	2,278,309
Trade receivables	16,939,295	20,693,854
Contract assets	24,043	46,834
Financial assets measured at amortized cost	1,438	3,721
Financial assets at fair value through profit or loss	39,289,630	25,844,992
Cash and cash equivalents	2,988,946	8,627,004
Total current assets	77,253,535	69,136,977
Total Assets	412,092,225	405,519,916
EQUITY
Common stock	108,907,931	108,907,931
Treasury shares	6,037,989	6,037,989
Cost of acquisition of treasury shares	(10,924,539)	(10,924,539)
Additional paid-up capital	(3,169,112)	(3,169,112)
Legal reserve	12,779,853	10,741,238
Reserve for capital expenditures, acquisition of treasury shares and/or dividends	121,274,267	82,540,576
Accumulated retained earnings	32,317,790	40,772,306
Non-controlling interests	110	98
Total equity	267,224,289	234,906,487
Non-current liabilities
Deferred tax liabilities	21,248,327	20,063,665
Taxes payables	14,285	0
Contract liabilities	11,717,412	10,963,157
Loans	90,694,136	100,121,274
Total non-current liabilities	123,674,160	131,148,096
Current liabilities
Provisions	1,834,094	2,524,233
Contract liabilities	1,045,454	978,575
Other payables	286,555	619,970
Taxes payables	944,696	1,297,426
Income tax payable	8,283	17,067,810
Payroll and social security taxes payable	2,629,829	2,774,569
Loans	3,919,929	2,299,738
Derivative financial instruments	0	82,329
Trade payables	10,524,936	11,820,683
Total current liabilities	21,193,776	39,465,333
Total liabilities	144,867,936	170,613,429
Total equity and liabilities	$ 412,092,225	$ 405,519,916

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY - ARS ($)	Total	Total attributable to equity holders [Member]	Shareholders Contributions, Total Common Stock [Member]	Shareholders Contributions, Common Stock [Member]	Shareholders Contributions, Inflation Adjustment to Common Stock [Member]	Shareholders Contributions, Treasury Shares, Common Stock [Member]	[1]	Shareholders Contributions, Treasury Shares, Inflation Adjustment to Common Stock [Member]	[1]	Acquisition Cost of Treasury Shares [Member]	[1]	Additional Paid-up Capital [Member]	[2]	Retained Earnings, Accumulated Retained Earnings [Member]	Retained Earnings, Legal Reserve [Member]	Retained Earnings, Reserve for Capital Expenditures, Acquisition of Treasury Shares and/or Dividends [Member]	Retained Earnings, Subtotal [Member]	Non-Controlling Interests [Member]
Balance at beginning of period at Dec. 31, 2019	$ 192,471,402,000	$ 192,471,290,000	$ 108,851,663,000	$ 784,608,000	$ 112,695,920,000	$ 9,887,000		$ 1,455,505,000		$ (2,925,145,000)		$ (3,169,112,000)		$ 54,504,557,000	$ 7,695,275,000	$ 21,419,795,000	$ 83,619,627,000	$ 112,000
Treasury shares purchase	(7,999,394,000)	(7,999,394,000)	(7,999,394,000)	(31,847,000)	(4,540,750,000)	31,847,000		4,540,750,000		(7,999,394,000)		0		0	0	0	0	0
Resolutions of the Ordinary and Extraordinary Shareholders' Meeting
Legal reserve	0	0	0	0	0	0		0		0		0		(2,562,853,000)	2,562,853,000	0	0	0
Dividends payment	0	0	0	0	0	0		0		0		0		0	0	0	0	0
Derecognition of reserves	0	0	0	0	0	0		0		0		0		21,419,795,000	0	(21,419,795,000)	0	0
Reserve for capital expenditures, acquisition of treasury shares and/or dividends	0	0	0	0	0	0		0		0		0		(73,361,499,000)	0	73,361,499,000	0	0
Non-controlling interests dividends payment	(47,000)	0	0	0	0							0		0	0	0	0	(47,000)
Comprehensive income for the year	9,662,214,000	9,662,187,000	0	0	0	0		0		0		0		9,662,187,000	0	0	9,662,187,000	27,000
Balance at end of period at Dec. 31, 2020	194,134,175,000	194,134,083,000	100,852,269,000	752,761,000	108,155,170,000	41,734,000		5,996,255,000		(10,924,539,000)		(3,169,112,000)		9,662,187,000	10,258,128,000	73,361,499,000	93,281,814,000	92,000
Resolutions of the Ordinary and Extraordinary Shareholders' Meeting
Legal reserve	0	0	0	0	0	0		0		0		0		(483,110,000)	483,110,000	0	0	0
Derecognition of reserves	0	0	0	0	0	0		0		0		0		73,361,499,000	0	(73,361,499,000)	0	0
Reserve for capital expenditures, acquisition of treasury shares and/or dividends	0	0	0	0	0	0		0		0		0		(82,540,576,000)	0	82,540,576,000	0	0
Comprehensive income for the year	40,772,312,000	40,772,306,000	0	0	0	0		0		0		0		40,772,306,000	0	0	40,772,306,000	6,000
Balance at end of period at Dec. 31, 2021	234,906,487,000	234,906,389,000	100,852,269,000	752,761,000	108,155,170,000	41,734,000		5,996,255,000		(10,924,539,000)		(3,169,112,000)		40,772,306,000	10,741,238,000	82,540,576,000	134,054,120,000	98,000
Resolutions of the Ordinary and Extraordinary Shareholders' Meeting
Legal reserve	0	0	0	0	0	0		0		0		0		(2,038,615,000)	2,038,615,000	0	0	0
Derecognition of reserves	0	0	0	0	0	0		0		0		0		82,540,576,000	0	(82,540,576,000)	0	0
Reserve for capital expenditures, acquisition of treasury shares and/or dividends	0	0	0	0	0	0		0		0		0		(121,274,267,000)	0	121,274,267,000	0	0
Comprehensive income for the year	32,317,802,000	32,317,790,000	0	0	0	0		0		0		0		32,317,790,000	0	0	32,317,790,000	12,000
Balance at end of period at Dec. 31, 2022	$ 267,224,289,000	$ 267,224,179,000	$ 100,852,269,000	$ 752,761,000	$ 108,155,170,000	$ 41,734,000		$ 5,996,255,000		$ (10,924,539,000)		$ (3,169,112,000)		$ 32,317,790,000	$ 12,779,853,000	$ 121,274,267,000	$ 166,371,910,000	$ 110,000

[1] As of December 31, 2022, 2021 and 2020 corresponds to 41,734,225 shares of par value Ps. 1 each, equivalent to 5.25% of the share capital. The acquisition cost of these shares amounted to Ps. 10,924,539. See Note 19.b) to the consolidated financial statements.

[2] See Note 19.b).

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CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY (Parenthetical) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Equity [Abstract]
Acquisition cost	$ 10,924,539	$ 10,924,539
Treasury Shares [Member]
Equity [Abstract]
Shares issued (in shares)	41,734,225	41,734,225	41,734,225
Par value (in pesos per share)	$ 1	$ 1	$ 1
Percentage of share capital	5.25%	5.25%	5.25%
Acquisition cost	$ 10,924,539	$ 10,924,539	$ 10,924,539

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CONSOLIDATED STATEMENTS OF CASH FLOWS - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
CASH FLOWS PROVIDED BY OPERATING ACTIVITIES
Total comprehensive income for the year	$ 32,317,802	$ 40,772,312	$ 9,662,214
Reconciliation of total comprehensive income to cash flows provided by operating activities:
Depreciation of property, plant and equipment	19,572,669	18,721,149	18,115,502
Derivative financial instrument results	127,585	157,227	(1,321,859)
Disposal of property, plant and equipment	96,242	125,836	102,586
Share of gain from associates	(90,138)	(41,347)	(62,657)
Increase in provisions	775,831	1,026,961	955,990
Interest expense accrual, net	6,537,595	8,392,366	9,455,473
Interest (loss) / income on other financial assets other than cash and cash equivalents	(21,176,519)	3,559,483	22,890,324
Income tax	17,061,153	24,810,849	12,950,061
Impairment of PPE	0	0	9,156,072
Notes repurchase result	1,030,169	806,841	(1,174,202)
Allowance for doubtful accounts	0	(129,715)	279,520
Foreign exchange loss, net	28,102,079	12,922,876	33,974,755
Loss on net monetary position	(9,107,531)	(21,839,164)	(20,638,648)
Changes in assets and liabilities:
Trade receivables	(7,812,886)	(10,879,283)	(893,154)
Other receivables	(6,510,381)	(8,226,280)	(1,627,647)
Inventories	(663,941)	(1,165,062)	(775,818)
Trade payables	4,439,683	5,261,196	422,732
Contract assets	0	186,898	168,414
Payroll and social security taxes	1,157,960	538,358	1,468,758
Taxes payables	310,109	644,834	18,523
Other payables	(32,423)	31,745	42,089
Provisions	(20,248)	(9,751)	(23,737)
Interest paid	(5,725,137)	(7,304,538)	(8,077,195)
Income tax paid	(25,687,559)	(8,360,256)	(3,430,707)
Contract liabilities	821,246	(906,573)	254,990
Derivative financial instruments payment	(109,299)	(73,392)	1,945,363
Cash flows provided by operating activities	35,414,061	59,023,570	83,837,742
CASH FLOWS USED IN INVESTING ACTIVITIES
Additions to property, plant and equipment	(25,307,541)	(18,794,792)	(22,844,489)
Dividends received	0	354,492	0
Financial assets not considered cash equivalents	(14,908,086)	(40,550,286)	(65,621,123)
Cash flows used in investing activities	(40,215,627)	(58,990,586)	(88,465,612)
CASH FLOWS PROVIDED BY / (USED IN) FINANCING ACTIVITIES
Payment of loans	(86,187)	0	(3,981,411)
Proceeds from loans	6,164,853	0	0
Cost of acquisition of treasury shares	0	0	(7,999,394)
Dividends paid	0	0	(47)
Cost of repurchase of notes	(2,452,516)	(1,869,224)	(2,939,684)
Cash flows provided by / (used in) financing activities	3,626,150	(1,869,224)	(14,920,536)
NET DECREASE IN CASH AND CASH EQUIVALENTS	(1,175,416)	(1,836,240)	(19,548,406)
Cash and cash equivalents at the beginning of the year	8,627,004	13,682,131	39,088,735
Foreign exchange gain on Cash and cash equivalents	292,549	629,531	2,236,421
Monetary results effect on Cash and cash equivalents	(4,755,191)	(3,848,418)	(8,094,619)
Cash and cash equivalents at the end of the year	$ 2,988,946	$ 8,627,004	$ 13,682,131

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BUSINESS DESCRIPTION

12 Months Ended

Dec. 31, 2022

BUSINESS DESCRIPTION [Abstract]

BUSINESS DESCRIPTION

1. BUSINESS DESCRIPTION

Business Overview

Transportadora de Gas del Sur S.A. (“tgs” or the “Company”) is one of the companies created as a result of the privatization of Gas del Estado S.E. (“GdE”). tgs commenced operations on December 28, 1992 and it is mainly engaged in the Transportation of Natural Gas, and Production and Commercialization of natural gas Liquids (“Liquids”). tgs’s pipeline system connects major natural gas fields in southern and western Argentina with natural gas distributors and industries in those areas and in the greater Buenos Aires area. The natural gas transportation license to operate this system was exclusively granted to tgs for a period of thirty-five years (“the License”). tgs is entitled to a one-time extension of ten years provided that it has essentially met the obligations imposed by the License and by the Ente Nacional Regulador del Gas (National Gas Regulatory Body or “ENARGAS”). The General Cerri Gas Processing Complex (the “Cerri Complex”), where tgs processes natural gas by extracting liquids, was transferred from GdE along with the gas transmission assets. tgs also provides midstream services, which mainly consist of gas treatment, removal of impurities from the natural gas stream, gas compression, gas transportation in fields, wellhead gas gathering and pipeline construction, operation and maintenance services. Also, telecommunications services are provided through the subsidiary Telcosur S.A. (“Telcosur”). These services consist of data transmission services through a network of digital terrestrial radio relay.

Subsequently, the corporate purpose of the Company was modified to incorporate the development of complementary activities, incidental, linked and / or derived from natural gas transportation, such as the generation and commercialization of electric power and the provision of other services for the hydrocarbon sector in general.

Major Shareholders

tgs’s controlling shareholder is Compañía de Inversiones de Energía S.A. (“CIESA”), which holds 51% of the common stock. CIESA is under joint control and in equal parts of: (i) Pampa Energía S.A. (“Pampa Energía”) with 50%; (ii) Grupo Inversor Petroquímica S.L. (member of the GIP Group, led by the Sielecki family) and PCT L.L.C. with the remaining 50%. Local and foreign investors hold the remaining ownership of tgs’s common stock.

The following table shows the organizational structure, shareholders and related parties of tgs as of December 31, 2022:

44%, 24%, 8%, 12%, 5%, 51%, 49%, 51%, 49%, 99.98%, 0.02%, 80%, 15%, 5%, 100%, 49%, 25.5%, 20.4%, 5.1%

Economic context

The Company operates in a complex economic context whose main variables have recently had strong volatility as a result of health events generated by the COVID19 pandemic, political and economic events both domestically and internationally.

During the first quarter of 2022, Argentina and the IMF reached an agreement where fiscal and monetary goals were established and a refinancing of maturities was obtained. However, the inflationary inertia continues, and as of December 31, 2022, year-on-year inflation reached 94.8%.

In addition, the conflict between Russia and Ukraine has been a major factor of global destabilization that led to a significant increase in the price of commodities, including natural gas. In this context, on April 7, 2022, the Argentine Government announced an agreement for the supply of natural gas from Bolivia during the winter period. The increase in natural gas prices could negatively affect Argentina’s current fiscal imbalance. Also, the availability and price of natural gas are key factors for the normal development of the Cerri Complex’s Liquids production activities.

The main macroeconomic issues and the measures adopted by the Government are described below:

Economic activity, poverty and unemployment

In recent years, the Argentine economy suffered a significant impact from the crisis generated by COVID-19 to the difficult moment that the international economy is experiencing due to high inflation and the conflict between Russia and Ukraine.

In this sense, after the abrupt economic slowdown produced in 2020 as a result of the sanitary measures imposed, the economy has begun a path of recovery in 2021, reaching an increase of 10.4% in the Monthly Estimator of Economic Activity (“EMAE”). This trend was reduced during 2022, showing that indicator a positive variation, as of November of that year, of 2.6% year-on-year. Recent estimates predict that given the volatile Argentine and international situation, economic growth would slow down during 2023.

Additionally, the unemployment rate presented a rate of 7.1% for the third quarter of 2022, according to the latest information provided by INDEC.

Likewise, the pandemic has had a profound initial impact on the lowest-income sectors. The latest official statistical data available from INDEC corresponds to the first semester of 2022, and indicates that in that period poverty reached 36.5%.

Fiscal imbalance

The primary fiscal deficit continued to be high, amounting in 2022 to 2.4% of the Gross Domestic Product (“GDP”). For its part, the financial deficit amounted to 4.2% of GDP. The reduction compared to 2021 was mainly due to the reorganization of the fiscal accounts carried out in order to meet the goals agreed with the IMF in the Extended Facilities Program.

Tariff policy

Reducing the fiscal deficit is one of the central issues within the framework of the principle of agreement with the IMF, and a large part of the deficit is explained by the growth of subsidies that cover the delay with tariffs. Public services tariffs have been virtually (in some cases completely and in others partially) frozen for almost 24 months.

During 2022, public service companies only received temporary rate increases since the comprehensive rate review (“RTI”) renegotiation process has not been completed. In fact, towards the end of 2022, the Government extended its completion period until the end of 2023. For more information, see “Note 17 – Regulatory framework.”

Likewise, in order to encourage production, to reduce the impact on certain types of natural gas consumers and to reduce the subsidies paid to natural gas producers, as from November 2020, the Plan for the Promotion of Argentine Natural Gas Production - Supply and Demand Scheme 2020-2024 was established through Decree No. 892/2020 (the “Gas.Ar Plan”).

Monetary imbalance and inflation

The country faces certain monetary imbalances aggravated by the high level of monetary issue as a result of the assistance measures adopted by the Government, thus pressing the international reserves of the Banco Central de la República Argentina (“BCRA”). The fall in the BCRA’s international reserves, accompanied by an increase in its monetary liabilities, has led to a tightening of the foreign exchange regulations that imposed restrictions on the accumulation and consumption of foreign currency and payments abroad, which in turn generated a significant gap between the official exchange rate and that of freer trading venues. For further information, see “Note 16 - Financial Risk Management”.

In order to deal with this situation, the Government has adopted several measures, among which we can mention: maximum price plans for certain food products, limitations to increases in utility tariffs and a limited exchange rate devaluation policy.

According to the latest Survey of Market Expectations (“REM”) carried out by the BCRA corresponding to December 2023, the median resulting from the estimates made by the 37 participants of the REM, showed an expected inflation of 110% for 2023.

Public debt

In 2022, an extremely important milestone was achieved, which was the agreement reached with the International Monetary Fund (“IMF”) for a new Extended Facilities Program. With a duration of 30 months, disbursements are made over 10 years, four and a half years of grace, this program allows the country to postpone its maturities with the agency and strengthen its reserves in the short term. Among the commitments assumed is gradual fiscal consolidation -reaching equilibrium in 2025- together with the reduction of monetary financing of the deficit and the accumulation of reserves to gain some freedom in monetary policy.

Exchange market

The low level of reserves in the BCRA has led the National Government to maintain a very restrictive exchange control for the purchase of foreign currency in the single free market for foreign exchange (“MULC”), in which the price of the US dollar at 31 December 2022 was $176.96 (buyer) and $177.16 (seller), representing an increase of approximately 72%, well below inflation as measured by the CPI. However, as of December 31, 2022, the gap with respect to the alternative quotations of the US dollar obtained in the market was close to 100%.

Since the primary elections that took place in September 2021, the BCRA had to tighten the exchange rate clamp to try to stop the leak of foreign currency, establishing, among other measures, greater restrictions on access to the MULC for imports. For further information, see “Note 16.1.1. – Risk associated with exchange rate”.

The current economic context and in particular, the exchange market generates expectations that the local currency will continue to devaluate, being a relevant aspect the speed with which this issue may develop in the next months, as well as other restrictions and/or developments in the exchange market with effects on different aspects of the economic activity, such as foreign trade and others.

The Company’s management permanently monitors the evolution of the situations affecting its business, in order to determine the possible actions to be taken and identify the eventual impacts on its financial position and the results of its operations. The Company’s financial statements should be read considering these circumstances.

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CONSOLIDATED FINANCIAL STATEMENTS

12 Months Ended

Dec. 31, 2022

CONSOLIDATED FINANCIAL STATEMENTS [Abstract]

CONSOLIDATED FINANCIAL STATEMENTS

2. CONSOLIDATED FINANCIAL STATEMENTS

tgs presents its consolidated financial statements including Telcosur S.A. (“Telcosur”), CTG Energía S.A. (“CTG”) and TGSLatam Energía S.A. (“TGSLatam”), its consolidated subsidiaries, which are jointly referred to as “tgs” or “the Company”.

These consolidated financial statements were approved and authorized for issuance by the Company’s Board of Directors on April 25, 2023.

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BASIS OF PRESENTATION

12 Months Ended

Dec. 31, 2022

BASIS OF PRESENTATION [Abstract]

BASIS OF PRESENTATION

3. BASIS OF PRESENTATION

These consolidated financial statements have been prepared in accordance with International Financial Reporting Standards issued by the International Accounting Standards Board (“IASB”) and the International Financial Interpretations Committee (“IFRIC”), jointly the “IFRS”).

The CNV, in Title IV, Chapter III, Article 1 of the Rules has provided that listed companies must submit their consolidated financial statements by applying Technical Resolution No. 26 of the Argentine Federation of Professional Councils of Economic Sciences (“FACPCE”), which adopts the International Financial Reporting Standards (“IFRS”) issued by the IASB, its amendments and circulars for the adoption of IFRS that the FACPCE dictates in accordance with the provisions of that Technical Resolution.

The preparation of the consolidated financial statements in conformity with IFRS requires management to make accounting estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the consolidated financial statements, as well as the reported amounts of revenues and expenses during the reporting fiscal year. Estimates are used when accounting for the allowance for doubtful accounts, income taxes, provisions for legal claims and others, depreciations and recoverable value of assets. Actual results could be significantly different from such estimates.

The presentation in the statement of financial position distinguishes between current and non-current assets and liabilities. The assets and liabilities are those expected to be realized or settled within twelve months after the end of the reporting period under review, and those held for sale. The fiscal year begins on January 1 and ends on December 31 of each year. The economic and financial results are presented on a fiscal year basis.

The consolidated financial statements have been stated in terms of the measuring unit current as of December 31, 2022 in accordance with IAS 29 “Financial reporting in hyperinflationary economies” and are stated in thousands of Argentine pesos (“Ps.” Or “pesos”) which is the functional currency of the Company, unless otherwise stated. For further information, see Note 4.c).

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SIGNIFICANT ACCOUNTING POLICIES

12 Months Ended

Dec. 31, 2022

SIGNIFICANT ACCOUNTING POLICIES [Abstract]

SIGNIFICANT ACCOUNTING POLICIES

4. SIGNIFICANT ACCOUNTING POLICIES

4.a) New accounting standards

4.a 1) New standards and interpretations issued by the IASB effective for the years beginning on or after January 1, 2022 adopted by the Company

The new accounting standards, amendments and interpretations issued by the IASB that became effective as of January 1, 2022 and that have not had an impact on the Company’s consolidated financial statements are the following:

IAS 16 - Property, plant and equipment (“PPE”) – Proceeds before intended use

In May 2020, the IASB issued an amendment to IAS 16 that prohibits entities from deducting from the cost of an item of PPE the revenue from the sale of items produced while bringing that asset into use. Instead, an entity shall recognize the revenue from the sale of such items, as well as the costs of production of those items, in profit or loss.

This amendment became effective for annual periods that began on or after January 1, 2022 and should be applied retrospectively to items of PPE that are available for use from the beginning of the earliest period presented when the company first applies the amendment.

The amendments did not have a significant impact on the Company’s consolidated financial statements.

IAS 37: Onerous Contracts: Cost of Fulfilling a Contract

In May 2020, the IASB issued amendments to IAS 37 to specify which costs an entit should include when assessing whether a contract is onerous.

These amendments clarify the meaning of “costs to fulfill a contract”. Costs that relate directly to a contract for the supply of goods or services include both incremental costs and an allocation of costs directly related to contract activities.

These amendments became effective for annual reporting periods that began on or after January 1, 2022.

The amendments did not have a significant impact on the Company´s consolidated financial statements.

4.a.2) New IFRS issued that are not yet effective for the year beginning January 1, 2022.

The IFRS that potentially have an impact on the Company, which are not mandatory and have not been adopted early in the year beginning January 1, 2022, are listed below:

Classification of debt as current and non-current (amendment to IAS 1)

On January 23, 2020, the IASB issued the classification of debt as current and non-current, which amends IAS 1 Presentation of Financial Statements. These amendments affect the requirements of IAS 1 for the presentation of debt.

Specifically, it clarifies the criteria for classifying debt as non-current. The date of application of the amendment was set for fiscal years beginning on or after January 1, 2023, with retroactive application. The Company is evaluating the impact of these amendments for the presentation of debt.

IAS 12: “Income tax”

IAS 12 - Income Tax specifies how an entity accounts for income tax, including deferred tax, which represents tax to be paid or recovered in future periods.

The amendments clarify that the exemption defined in the standard to recognize deferred taxes when assets or liabilities are recognized for the first time is not applicable in the case of leases and provisions for decommissioning.

The amendments are effective for annual reporting periods beginning on or after January 1, 2023 and early application is permitted.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

IAS 8: “Accounting Policies, Changes in Accounting Estimates and Errors”

In February 2021, the IASB issued amendments to IAS 8, introducing a definition of “accounting estimates”. The amendments clarify the distinction between changes in accounting estimates and changes in accounting policies and the correction of errors. They also clarify how entities use measurement techniques and inputs to develop accounting estimates.

The modifications are effective for annual reporting periods that began on or after January 1, 2023.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

IAS 1: Disclosure of accounting policies – Practice Statement 2

In February 2021, the IASB issued amendments to IAS 1 and IFRS Practice Statement 2, Making Materiality, providing guidance and examples to help entities apply disclosure materiality judgments on accounting policies. The purpose of the amendments is to help entities provide information about accounting policies that is more useful, by replacing the requirement that entities disclose their “significant” accounting policies with “material” accounting policies and by adding guidance on how Entities apply the concept of materiality when making decisions about disclosures regarding accounting policies.

The modifications are effective for annual reporting periods that began on or after January 1, 2023.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

4.b) Consolidation

4.b.1) Subsidiaries

Subsidiaries are all entities over which the Company has control. The Company controls an entity when the Company is exposed to, or has rights to, variable returns from its involvement and has the ability to affect those returns through its power over the entity. Subsidiaries are fully consolidated from the date on which control is transferred to the group. They are deconsolidated from the date that control ceases. For this purpose and unless there are specific requirements, it is generally considered that tgs has control, when it has a participation equal to or greater than 50% of the available voting rights.

The accounting policies of the subsidiaries are consistent with the accounting policies adopted by the Company.

Inter-company transactions, balances and profit or loss from transactions between group companies are eliminated. Unrealized profit or loss are also eliminated.

Detailed data reflecting subsidiary control as of December 31, 2022 and 2021 is as follows:

		% of shareholding and voting
Company	Incorporation country	Direct			Indirect			Closing date	Main activity
Telcosur	Argentina		99.98	%		-		December 31	Telecommunication Services
CTG	Argentina		100	%		-		December 31	Electricity related services
TGSLatam	Bolivia		80	%		100	%	December 31	Hydrocarbons and Electrical power related services

For consolidation purposes for the year ended December 31, 2022, the financial statements of Telcosur and TGSLatam have been used at those dates. The subsidiary CTG does not record operations or significant assets and liabilities as of December 31, 2022 and 2021.

4.b.2) Associates

Associates are entities over which the group has significant influence but not control, generally accompanying a shareholding of between 20% and 50% of the voting rights. Investments in associates are accounted for using the equity method of accounting. Under the equity method, the investment is initially recognized at cost, and the carrying amount is increased or decreased to recognize the investor’s share of the profit or loss of the investee after the date of acquisition.

The Company accounted for the investments in its associates, under the equity method on the basis on the financial statements as of September 30, 2022 of Gas Link S.A. (“Link”), Transporte y Servicios de Gas en Uruguay SA (“TGU”) and Emprendimientos de Gas del Sur S.A. (“EGS”), under liquidation. Accounting policies of associates have been changed where necessary to ensure consistency with the policies adopted by the Company. The Company’s management is not aware of any significant subsequent events which affected the financial statements as of September 30, 2022 of Link, TGU and EGS (in liquidation) from this date to December 31, 2022.

Unrealized gains and losses resulting from transactions between tgs and the associate or joint venture are eliminated to the extent of the interest in the associate or joint venture.

In the table below, associates are disclosed, together with the percentage of shareholding and voting as of December 31, 2022 and 2021:

Company	% of shareholding and voting	Country	Main activity	Closing date
TGU	49.00%	Uruguay	Pipeline maintenance	December 31
EGS (“in liquidation”)	49.00%	Argentina	Pipeline exploitation and construction	December 31
Link	49.00%	Argentina	Pipeline exploitation and construction	December 31

4.b.3) Joint arrangement

As indicated in “Note 23 – Associates and Joint Arrangement”, on August 7, 2017, the Company proceeded to create a UT (similar to a joint operation) with SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A. (“SACDE”) (“UT”). This operation is evaluated as a joint agreement under the provisions included in “IFRS 11 - Joint Arrangements” since the parties have joint control of the operation, meaning that the decisions of the relevant activities are taken under the unanimous consent of the parties.

The Company has defined that the UT constitutes a joint operation given that it grants its participants a percentage of the rights over the assets and liabilities arising from each contract. Accordingly, the Company recognizes its share in the jointly operated assets, liabilities, revenues, costs and expenses.

Accounting policies applicable to the UT have been modified and adapted, if applicable, to ensure consistency with the policies adopted by the Company. For further information regarding the UT, see Note 23.

4.c) 
Foreign currency translation

4.c.1) Functional and presentation currency

The consolidated financial statements are presented in thousands of Argentine Pesos, which is the Company’s functional currency. Each subsidiary or associate determines its own functional currency based on the currency of the primary economic environment in which these entities operate.

4.c.2) Transactions and balances

Foreign currency transactions are translated into the functional currency using the exchange rate prevailing at the dates of the transactions or valuation where items are remeasured. Foreign exchange gains and losses resulting from the settlement of such transactions and from the translation at year-end exchange rates of monetary assets and liabilities denominated in foreign currencies are recognized in the profit or loss for the year.

Foreign exchange gains and losses are presented in the statement of comprehensive income within financial income and financial expenses, as appropriate.

4.c.3) Associates

The functional currency of the associate company TGU, which is located abroad, is the US dollar, because it is the currency in which it substantially generates its income and incurs its expenses. Assets and liabilities were converted into Argentine pesos using the exchange rate prevailing at the end of each year, their common stock and retained earnings at their historical exchange rates and results at average exchange rates.

4.d) Restatement to constant currency - Comparative Information

4.d.1) Regulatory framework

The consolidated financial statements as of December 31, 2022, including comparative figures, have been restated to take into account changes in the general purchasing power of the Company’s functional currency (the Argentine peso) in accordance with IAS 29 “Financial Reporting in hyperinflationary economies” (“IAS 29”) and CNV General Resolution No. 777/2018. As a result, the financial statements are stated in terms of the current unit of measurement at the 2022 balance sheet date.

IAS 29 requires that the financial statements of an entity that reports in the currency of a hyperinflationary economy, regardless of whether they are based on the historical cost method or the current cost method, are expressed in terms of the current unit of measurement at the closing date of the reporting period. In order to conclude on the existence of a hyperinflationary economy, the standard details a series of factors to be considered, among which is a cumulative inflation rate over three years that approaches or exceeds 100%.

The accumulated inflation in three years is over 100%. Likewise, both the National Government projections and other available projections indicate that this trend will not be reversed in the short term.

To evaluate the aforementioned quantitative condition, and also to restate the financial statements, the CNV has established that the series of indexes to be used for the application of IAS 29 is determined by the FACPCE. This series of indexes combines the National Consumer Price Index (“CPI”) as of January 2017 (base month: December 2016) with the Domestic Wholesale Price Index (“IPIM”), both published by the Institute National Statistics and Census (“INDEC”) until that date. For the months of November and December 2015, for which there is no information from the INDEC on the evolution of the IPIM, the variation in the CPI of the Autonomous City of Buenos Aires was applied.

Considering the aforementioned index, inflation was 94.79%, 50.94% and 36.14% in the years ended December 31, 2022, 2021 and 2020 respectively.

4.d.2) Restatement mechanism

The financial statements must be adjusted to consider changes in the general purchasing power of the currency, so that they are expressed in the current unit of measurement at the end of the reporting period. Said requirements also include all the comparative information of the financial statements, without modifying the decisions made based on the financial information corresponding to those financial years.

The figures as of December 31, 2021 and 2020, which are presented in these Consolidated Financial Statements for comparative purposes, arise from the restatement to the current unit of measure of the Financial Statements as of said dates, in accordance with IAS 29.

Restatement of the balance sheet

i. Monetary items (those with a fixed nominal value in local currency) are not restated, since they are already expressed in the current unit of measurement at the closing date of the reporting period. In an inflationary period, maintaining monetary assets generates loss of purchasing power and maintaining monetary liabilities generates a gain in purchasing power, provided that such items are not subject to an adjustment mechanism that compensates to some extent for these effects. The monetary loss or gain is included in the result of the period in which it is reported.

ii. The non-monetary items measured at their current values at the end of the reporting period are not restated for the purpose of their presentation in the balance sheet, but the adjustment process must be completed to determine in terms of a homogeneous unit of measurement the results produced by the holding of these non-monetary items.

iii. Non-monetary items measured at historical cost or at a fair value as of a date prior to the closing date of the reporting period are restated by coefficients that reflect the variation in the general price level from the date of acquisition or revaluation to the closing date, proceeding then to compare the restated amounts of those assets with the corresponding recoverable values.

iv. The restatement of non-monetary assets in the terms of the current unit of measurement at the end of the reporting period without an equivalent adjustment for tax purposes, results in a temporary taxable difference and the recognition of a deferred tax liability whose counterparty is recognized in the result of the period. For the closing of the subsequent period, the deferred tax items are restated for inflation to re-determine the charge to the result of the next period.

v. When the capitalization of costs for loans in non-monetary assets in accordance with IAS 23 is applicable, the portion of those costs that compensate the lender for the effects of inflation is not capitalized.

Restatement of the Comprehensive Income Statement

Revenues and expenses (including interest and foreign exchange differences) are restated from the date of their booking, except for those items of the result that reflect or include in their determination the consumption of assets measured in purchasing power of a date before the consumption booked, which are restated based on the date of origin of the asset to which the item is related (for example, depreciation and other consumption of assets valued at historical cost); and also those results that arise from comparing two measurements expressed in purchasing power currency of different dates, for which it is necessary to identify the amounts compared, restate them separately, and make the comparison, but with the amounts already restated.

The result of the exposure to the change in the purchasing power of the currency (monetary results) is presented in a separate line and reflects the effect of inflation on the monetary items.

Restatement of the statement of changes in equity

As of the transition date (January 1, 2016), the Company applied the following special rules:

i. The components of the capital stock were restated from the dates they were contributed.

ii. Reserved earnings were maintained at the date of transition at their nominal value (legal amount without restatement).

iii. The restated unallocated results were determined by the difference between the net assets restated at the transition date and the rest of the initial equity components expressed as indicated in the preceding sections.

iv. After the restatement at the transition date, all the components of the equity are restated by applying the general price index from the beginning of the period, and each variation of those components is restated from the date of contribution or from the moment in which is added by any other means.

Restatement of the statement of cash flows

IAS 29 requires that all items in this statement should be restated in terms of the current unit of measurement as of the closing date of the period for which it is reported.

The monetary result generated by cash and cash equivalents is presented in the Statement of Cash Flows separately from cash flows from operating, investing and financing activities, as a specific item of the reconciliation between cash and cash equivalents at the beginning and at the end of the year.

4.e) Financial instruments

4.e.1) Financial assets

Recognition and initial measurement

Financial assets are classified, at the time of initial recognition, as:

• Financial assets subsequently measured at amortised cost, and

• Financial assets subsequently measured at fair value (either with changes in other comprehensive income or with changes in results).

The classification of financial assets at initial recognition depends on the financial asset’s contractual cash flow characteristics and the Company’s business model for managing them. For additional information, see Note 16.2.1.

Subsequent measurement

After initial recognition, financial assets are measured according to their initial classification according to the following categories:

Financial assets measured at amortised cost

It is the most relevant category used by the Company, financial assets are classified and measure at amortised cost if both of the following conditions are met:

• The financial asset is held within a business model with the objective to hold financial assets in order to collect contractual cash flows; and

• The contractual terms of the financial asset give rise on specified dates to cash flows that are solely payments of principal and interest on the principal amount outstanding.

Financial assets measured at amortised cost are subsequently measured using the effective interest method.

Gains and losses are recognized in the Statement of Comprehensive Income under financial results when the asset is derecognized, modified or impaired.

Financial assets at fair value through OCI (Debt instruments)

Corresponds to financial assets that are maintained in a business model whose objective is achieved by obtaining contractual cash flows and selling them.

Unrealized gains or losses arising from changes in fair value are recognized as other comprehensive income, except for the accrual of interest, exchange rate difference and the impairment of such assets that are recognized as financial results in the Statement of Comprehensive Income. At the time the asset is written off, the accumulated gain or loss is recognized as a financial result and it is eliminated from the respective reserve.

As of December 31, 2022 and 2021, the Company has not recognized any financial assets under this category.

Financial assets designated at fair value through OCI (equity instruments)

Upon initial recognition, the Company can elect to classify irrevocably its equity investments as equity instruments designated at fair value through OCI when they meet the definition of equity under IAS 32.

Gains and losses on these financial assets are never recycled to profit or loss. Dividends are recognized as other income in the Statement of Comprehensive Income when the right of payment has been established, except when the Company benefits from such proceeds as a recovery of part of the cost of the financial asset, in which case, such gains are recorded in OCI. Equity instruments designated at fair value through OCI are not subject to impairment assessment.

As of December 31, 2022 and 2021, the Company has not recognized any financial assets under this category.

Financial assets at fair value through profit or loss

In the event that financial assets are not classified according to the aforementioned categories, they will be subsequently measured at fair value, presenting gains or losses arising from changes in fair value in the income statement within financial results in the year in which they are originated.

Impairment of financial assets

The Company applies the Expected Credit loss (“ECL”) model for those financial assets accounted for at amortised cost or at fair value through OCI. The ECL is based on the difference between the contractual cash flows due in accordance with the contract and the cash flows that the Company expects to receive, discounted at an approximation of the original effective interest rate. To this end, the Company evaluates various factors, including credit risk, historical trends and other available information.

The application of this model implies recognition of:

• Expected credit losses within of 12 months: these are expected credit losses that result from possible default events within 12 months after the filing date; and

• Expected credit losses during the life of the asset: these are expected credit losses that result from possible events of default during the expected life of a financial instrument.

In case a loss allowance is recognized, the carrying amount of the asset is reduced through an impairment account and the amount of the loss is presented in the Statement of Comprehensive Income at the time it occurs. Subsequent recoveries of amounts previously written off are credited in the same line item.

The impairment tests performed on accounts receivable are described in Note 4.h.

4.e.2) Financial liabilities

Includes trade payables, loans, other payables and certain payroll and social security taxes payable.

Recognition and initial measurement

Financial liabilities are classified, at initial recognition, as subsequently measured at amortised cost or at fair value through profit or loss, as appropriate.

All financial liabilities are recognized initially at fair value net of transaction costs.

They are classified in current liabilities, except those whose maturity exceeds twelve months, which are classified as non-current liabilities.

Subsequent measurement

Financial liabilities at fair value through profit or loss

Includes financial liabilities measured at fair value. As of December 31, 2022 there are no instruments classified in this category. As of December 31, 2021 the Company includes derivative financial instruments under this category.

Financial liabilities at amortised cost

The Company includes financial liabilities with fixed or determinable payments that are not quoted in an active market. Current liabilities are included, except those whose maturity exceeds twelve months including premiums, discounts and direct expenses, which are included as non-current liabilities. They are measured using the effective interest method. As of December 31, 2022 and 2021, all of the Company’s financial liabilities were classified in this category.

Offsetting of financial instruments

Financial assets and liabilities are offset when there is a legally enforceable right to offset the recognized amounts and there is an intention to settle on a net basis, or realize the asset and settle the liability simultaneously.

4.f) Derivative financial instruments

Derivative financial instruments are recognized at their fair value at inception and subsequently measured at their fair value and disclosed as assets or liabilities depending if it is gain or loss. The results of derivative financial instruments are classified under “Financial income / expenses” in the statement of comprehensive income, or in the other comprehensive income if hedge accounting is applied.

Derivative financial instruments are measured in accordance with IFRS 13 “Fair value measurement”.

The method of recognizing the resulting gain or loss depends on whether the derivative is designated as a hedging instrument or not and, according to the nature of the item being hedged.

As of December 31, 2021, the Company had contracted forward operations for the purchase of US dollars, (which qualify as exchange-traded futures), which are disclosed in the item “Derivative financial instruments” of the Statement of Financial Position, for which the application of the hedge accounting as defined by IFRS 9 has not been elected. The (loss) / gain for the year was included in the line “Derivative financial instruments result” in “Financial Results” in the Statement of Comprehensive Income. For more information, see notes 16.1.1 and 16.1.3 to these financial statements.

4.g) Inventories

Inventories consist of natural gas (in excess of the “Line Pack”, classified as property, plant and equipment) in the Company’s pipeline system, and the liquids stored obtained from natural gas processing at the Cerri Complex.

Inventories are measured at the lower of cost restated for the inflation effects as mentioned in Note 4.d. or net realizable value. Cost is determined using the weighted average cost method. The cost of inventories includes expenditure incurred in purchasing and production and other necessary costs to bring them to their existing location and condition.

The net realizable value is the estimated selling price in the ordinary course of business less the estimated cost of completion and the estimated costs to make the sale.

The assessment of the recoverable value of these assets is made at each reporting date, and the resulting loss is recognized in the statement of comprehensive income when the inventories are overstated.

4.h) Trade receivables and other receivables

Trade receivables are amounts due from customers for goods and services performed in the ordinary course of business. Contract assets are unbilled amounts due to customers related to works in progress.

Trade receivables, contract assets and other receivables are recognized initially at fair value and subsequently measured at amortised cost using the effective interest method, less allowance for trade receivables.

The Company applies the simplified approach to measuring expected credit losses for trade receivables, contract assets and other receivables. For this purpose, customers have been grouped based on shared credit risk characteristics, the existence of guarantees, historical credit losses experienced and the existence of judicial proceedings aimed at obtaining payment. Once each group was defined, an expected uncollectibility rate calculated based on historic default rates adjusted to future economic conditions was defined.

Impairment losses on trade receivables and contract assets are presented as net impairment losses within operating profit. Subsequent recoveries of amounts previously written off are credited against the same line item.

4.i) Cash and cash equivalents

Cash and cash equivalents includes cash in hand, deposits with banking institutions and other short-term, highly liquid investments with original maturities not exceeding three months and without being subject to a risk of a significant change of value.

4.j) Property, plant and equipment (“PPE”)

Assets transferred from the privatization of GdE: The value of these assets was determined based on the price paid for the acquisition of 70% of the Company’s common stock, which amounted to U.S.$ 561.2 million. This price was the basis to determine a total value of common stock of U.S.$ 801.7 million, which, when added to the debt assumed under the Company’s privatization agreement (the “Transfer Agreement”) of U.S.$ 395.0 million, resulted in a total value for PPE of U.S.$ 1,196.7 million. Such value, converted at the exchange rate in effect as of the date of the Transfer Agreement, has been restated for the effects of inflation as mentioned in Note 4.d, and less accumulated depreciation.

Line pack: It represents the natural gas in the transportation system that is necessary to keep the system at operating capacity, valued at acquisition cost and restated for the effects of inflation as mentioned in Note 4.d.

Materials: Materials are recognized at historical cost restated in accordance with Note 4.d. Consumption is restated based on the origin date of the acquisition of the asset.

Other items of PPE: have been valued at acquisition cost restated for the effects of inflation as mentioned in Note 4.d, and net of accumulated depreciation. They include, mainly, all the investments made to achieve system integrity and public safety equal to those required by international standards. Such investments included, among others, the costs of survey programs related to internal and external pipeline inspection, cathodic protection, pipeline replacement and recoating, and the facilities affected to the Production and Commercialization of Liquids and Other Services segment.

PPE additions are recorded at acquisition or construction cost less accumulated depreciation and impairment losses (if applicable), except land, which is recorded at historical cost acquisition minus any impairment (if applicable), all this restated for the effects of inflation as mentioned in Note 4.d. The cost includes the cost of replacing significant components and the borrowing costs derived from loans that finance its construction to the extent that the requirements for recognition as assets are met.

Subsequent costs restated for the effects of inflation as mentioned in Note 4.d. are included in the carrying amount of the asset or recognized as a separate asset, as appropriate, only when it is probable that future economic benefits associated with the item will flow to the Company and the cost of the item can be reliably measured. The carrying amount of a replaced component is written off. In the same way, when a major maintenance is carried out, they are added to the cost of the equipment if the recognition criteria are satisfied, eliminating any remaining non-depreciated remaining value restated for the effects of inflation as mentioned in Note 4.d, if any, of previous overhaul.

In this sense, Resolutions No. 1660/2000 (“Resolution 1660”) and No. 1903/2000 (“Resolution 1903”) issued by ENARGAS include definitions about the costs that should be considered as improvements or maintenance expenses. All other repairs and maintenance are charged to the statement of comprehensive income when incurred.

In accordance with IAS 23, the Company capitalizes financial expense on long term construction projects, until the moment in which the asset is in conditions for its use. Capitalization of borrowing costs is carried out considering the provisions of IAS 29, recording as an expense in the Statement of Comprehensive Income the part of the borrowing costs that compensates for inflation during the same period. As of December 31, 2022 and 2021 there have not been capitalized borrowing costs.

Depreciation related to natural gas transportation assets is computed under the straight -line method over the estimated useful lives of the specific assets, which are not exceeding the maximum useful lives established by ENARGAS through Resolutions 1660 and 1903.

For depreciation of all other PPE, the Company uses the straight-line method of depreciation based on the useful life assigned to each item.

Major maintenance costs are depreciated according to the estimated time until the next major maintenance planned. Regarding the capitalized financial costs, they are depreciated based on the remaining useful lives of those components of PPE that originated such capitalization.

The assets’ residual values and useful lives are reviewed, and adjusted if appropriate, at each reporting date. For further information, see Note 12.

The result generated by the disposal of PPE components is recognized in the year in which it is generated.

Impairment of non-financial assets: The Company assesses at each reporting period whether there is an indication that an individual component or a group of PPE may be impaired.

If any indication exists, the Company estimates the asset´s recoverable amount. An asset´s recoverable amount is the higher of the fair value less costs to sell that asset, and its value-in-use.

That amount is determined for and individual asset, unless the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets; in which case, the cash flows of the group of assets that form part of the cash-generating unit (“CGU”) to which the belong are taken.

Where the carrying amount of an individual asset or CGU exceeds its recoverable amount, the individual asset or CGU, as the case may be, is considered impaired and is written down to its recoverable amount. Impairment losses are recognized in the consolidated statement of comprehensive income.

In assessing value in use, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset for which the estimates of future cash flows have not been adjusted. To such end, the management makes estimates and assumptions of the economic conditions that will prevail throughout the useful life of the assets.

As a result of the factors mentioned above, actual cash flows and values could vary significantly from projected cash flows and the values derived from the discounting techniques used.

Impairment losses, if any, are recognized in the statement of comprehensive income.

As of December 31, 2022 and 2021, the book value of PPE did not exceed its recoverable value.

Infrastructure used in the natural gas transportation service: for its measurement and disclosure, the Company has evaluated the application of Interpretation No. 12 “Service Concession Agreements” (IFRIC 12) that sets the guidelines for the accounting of private entities that provide public services through a service concession agreement or a contract of a similar nature.

Considering the current terms and conditions of the License, tgs concluded that the License is outside the scope of IFRIC 12, as it is considered in substance to provide for an indefinite term because the infrastructure will never revert to the grantor and due to the characteristics of renewal of the License that give a similar result to what which would result from having obtained a perpetual right to operate the infrastructure.

The evaluation carried out and the conclusions reached by tgs are consistent with those of other transportation and natural gas distribution companies in Argentina that are subject to the similar regulations and license agreements. The evaluation was carried out jointly, when the transportation and distribution companies adopted the IFRS in Argentina in 2012, together with the FACPCE, the Buenos Aires Stock Exchange (Bolsas y Mercados Argentinos -“BYMA”) and the CNV, considering the contributions of ENARGAS with respect to the regulatory aspects of the License agreements. In this regard, the CNV issued General Resolution No. 613/2012, ratifying that IFRIC 12 does not apply to natural gas transportation and distribution licenses established under the regulatory framework described in Note 17.

4.k) Leases

Leases are recognized as a right-of-use asset and a corresponding liability at the date on which the leased asset is available for use by the Company. Each lease payment is allocated between the liability and the finance cost. The finance cost is expensed over the lease term to produce a constant periodic interest rate on the remaining balance of the liability for each period. The right-of-use asset is depreciated over the shorter of the useful life of the asset or the term of the contract.

Assets and liabilities arising from a lease are initially measured based on the present value of the lease. Liabilities include the net present value of the following lease payments:

a) Fixed payments, less any incentive receivable;

b) Variable lease payments;

c) Amounts expected to be collected as a guarantee of the residual value;

d) The exercise price of the lease option; and

e) Penalty payments for termination of the lease.

Lease payments are discounted using the interest rate implicit in the lease. If such rate cannot be determined, the Company’s incremental borrowing rate is used, which is the rate that tgs would have to pay to borrow the funds necessary to obtain an asset of similar value in a similar economic environment.

Right-of-use assets are measured at cost which comprises the following:

a) The amount of the initial measurement of the lease liability;

b) Any lease payments made on or before the commencement date less any lease incentives received;

c) Any initial direct costs; and

d) Restoration costs

These assets, which are subject to the risk of impairment, are depreciated on a straight-line basis over the shorter of the useful life of the leased asset or the lease term.

Payments associated with short-term leases and low-value assets are recognized on a straight-line basis as an expense in the Statement of Income. Short-term leases are those with a term of 12 months or less. Low-value assets comprise computer equipment, vehicles, small items of office furniture and real estate.

The Company has rights to use assets that are shown as part of Property, plant and equipment (see Note 12). Lease liabilities are shown under Financial Debt (see Note 13). For further information regarding the expense related to short-term and low value leases and the interest expense on lease liabilities, see Note 8.j. and 8.k., respectively.

4.l) Loans

Loans have been initially recorded at fair value net of direct attributable transaction costs. Subsequently, loans are valued at their amortised cost. Liabilities are disclosed as non-current when their maturity exceeds twelve months.

4.m) 
Trade payables

Trade payable are initially recognized at fair value. Subsequently they are measured at amortised cost using the effective tax method.

4.n) Income tax and deferred income tax

Income tax includes current tax and deferred income tax. Income tax is presented in the Statement of Comprehensive Income.

The current income tax is calculated on the basis of tax regulations in force at each reporting period. Management periodically evaluates positions taken in tax returns with respect to situations in which tax regulations are subject to interpretation and establishes provisions if applicable. As of December 31, 2022 and 2021, there are no provisions booked for this concept.

The Company has calculated income tax charges using the deferred tax method, which considers the effect of temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases.

Deferred income tax assets and liabilities are measured at undiscounted nominal value at the tax rates that are expected to apply in the year when the asset is realized or the liability is settled, based on tax rates and tax laws that have been enacted or substantively enacted at the reporting period rate (See Note 14).

A deferred tax is recognized on the temporary differences arising from investments in subsidiaries and associates, except for deferred tax liabilities where the Company is able to control the timing of the reversal of the temporary difference and it is probable that the reversal will not occur in the foreseeable future.

Deferred tax assets and liabilities are offset if the Company has a legally enforceable right to offset recognized amounts and when deferred tax assets and liabilities relate to income tax levied by the same tax authority on the same taxable entity or different taxable entities that intend to settle tax assets and liabilities on a net basis. Deferred tax assets are recognized to the extent that it is probable that future taxable income will be generated against which the temporary differences can be used.

The assets and liabilities generated by the application of the deferred tax were valued at their nominal amount considering the restatements for inflation mentioned in Note 4.d) and are classified as non-current assets or liabilities.

4.o) Provisions

The Company has recorded provisions related to legal actions, judicial court, claims and administrative proceedings, including interpretive questions of the current legislation and those of regulatory nature.

Provisions for legal claims and/or claims by third parties (“legal claims and others”) are recorded at the expected cancellation value when the Company has a present obligation as a result of a past event, it is probable that an outflow of resources will be required to settle the obligation; and the amount has been reliably estimated. Estimates are reviewed and adjusted, as the Company obtains additional information to be received.

4.p) Revenue recognition from contract with customers

Revenue is measured at the fair value of the consideration received or to be received, and represents amounts receivable for goods and/or services supplied. Revenue is recognized when the control of goods or services is transferred to the customer and the consideration is determined by an amount that reflects the consideration that the Company expects to receive.

Tax on exports and turnover tax are disclosed as Selling Expenses.

The following are the accounting policies of the Company for the recognition of revenue of each of the business segments defined by our management:

Natural Gas Transportation

Natural Gas transportation services includes: (i) firm natural gas transportation, whose revenues are recognized when the capacity is reserved and paid for regardless of actual usage by the customer, (ii) interruptible natural gas transportation and exchange and displacement services whose revenues are recognized when services are rendered and (iii) the operation and maintenance service of the assets affected by the natural gas transportation service corresponding to the expansions promoted by the National Government and whose ownership corresponds to the trusts created for such purpose whose revenues are recognized when services are rendered.

The applicable rates arise from the tariff tables published by ENARGAS. Thus Company’s revenues are recognized by the amount for which it will be entitled to receive as consideration.

At the end of each month, tgs recognizes, over the time, its revenues from sales equivalent to the firm reserved capacity, the volumes of natural gas transported under the modalities of interruptible and exchange and displacement and by the operation and maintenance services. In return, a trade receivable is recognized which represents an unconditional right that the Company has to receive the consideration owed by the customer. On the other hand, the billing of the service is done monthly and according to the guidelines established by ENARGAS, the consideration is received within said calendar month.

Liquids Production and Commercialization

This business segment includes: (i) production and commercialization of liquids on our own account which revenues are recognized in a point in time, and (ii) other liquid services which revenues are recognized over the time.

Liquids Production and Commercialization in the domestic market

In the domestic market, tgs sells the production of propane and butane to LPG retailers in the framework of the programs created by the National Government to supply the domestic market. The sale prices are determined by the ex-Secretary of Hydrocarbon Resources (“SHR”). For more information, see Note 17 - Regulatory framework – b) Regulatory framework for non-regulated segments - to these consolidated financial statements.

The price of those tons of propane and butane that are not sold within the framework of the aforementioned programs is determined by the ex-Ministry of Energy and Mining (“ex MINEM”) based on the international reference prices.

Regarding ethane sales, they are made to PBB Polisur S.R.L. (“PBB”), the only customer to whom this product is sold. To estimate transaction price, the Company uses the most probable amount method. In this regard, the Company only recognizes those transactions where it is highly probable that they will not be reversed in the future.

Liquids Production and Commercialization in the foreign market

In the foreign market, the Company markets propane, butane and natural gasoline to international traders (“traders”) and other clients of worldwide renown, some of them through trucks.

These sales are made under short-term contracts (less than one year), with the price determined as reference to international prices plus / minus a fixed amount per ton sold. There are no variable consideration components in these contracts.

For both domestic and foreign market sales, tgs transfers control and recognizes revenues when the products are delivered to the customer and therefore the product has been accepted and there is no evidence of the existence of pending obligations by the Company. It is at that moment when a trade receivable is recognized given that the receipt of the consideration is unconditional and only the passage of time is the only requirement for receiving the consideration owed by the customer.

Other liquids services

The Liquids production and commercialization segment also comprises reception, storage and dispatch of the liquids from the facilities located in Puerto Galván.

Revenues from sales are recognized when the service is effectively rendered, that is, after the dispatch to each vessel. The price is agreed by the parties being a fixed amount per ton of product dispatched, there being no variable components in them.

These services are billed monthly, at which time an unconditional right to receive the consideration from the client arises.

Subsidies

As part of its participation in propane and butane supply programs in the local market carried out by the National Government, (for more information see “Note 17 - Regulatory Framework - b) Regulatory framework for non-regulated segments”), the Company receives from the Secretary of Energy a series of subsidies that are recognized in accordance with the provisions of IAS 20 “Accounting for government grants and disclosures of government assistance” because they correspond to economic compensations calculated as the difference between the sale prices of the products determined in accordance with the legislation in force and the reference prices calculated by the Secretary of Energy.

Subsidies are recognized at fair value whenever there is reasonable assurance that will be received and that the product has been delivered. They are presented within the caption “Revenues” of the statement of comprehensive income.

Other services

The services included in the Other Services segment consist mainly in (i) treatment, removal of impurities and natural gas compression, including the collection and transport of natural gas (ii) inspection and maintenance of pipelines and compressor plants, (iii) services of steam generation for electricity production and management services for expansion works and steam generation for the production of electricity and (iv) natural gas transportation services in Vaca Muerta.

Revenues from sales of this business segment are recognized over the time in the period in which the service is provided. The sale price is determined according to what arises from the contractual conditions agreed between tgs and its customers. In all cases, the recognition and billing of sales income is made on a monthly basis so that at that time a sales credit is recorded.

Revenues from the participation in the joint venture, which correspond to the construction activities provided by the joint venture, are recognized based on the stage of completion of the contractual activity (percentage of completion method), considering the estimated final margin of the work. To apply the percentage of completion method, the revenue recognized at the end of the period will correspond to the total contractual revenue multiplied by the actual percentage of completion, based on the proportion of the total direct contractual costs incurred to date, and the total direct contractual costs, including the estimated costs to complete the construction. Costs incurred in excess of the costs associated with revenue are recognized in Contract assets.

Telecommunications

Revenues from the provision of Telecommunications services are recognized in the statement of comprehensive income at the time of effective performance of the service. The sale price is determined according to what arises from the contractual conditions agreed between tgs and its customers. The consideration is determined as a fixed monthly amount. In all cases, the recognition and billing of sales income is made on a monthly basis so that at that time a sales receivable is recorded.

Financial components

The Company does not have any contracts where the period between the transfer of the promised goods or services to the customer and payment by the customer exceeds one year. As a consequence, the Company does not adjust any of the transaction prices for the time value of money.

4.q) Contract liabilities

Mainly consist of pre-payments for services made by customers in order to finance the works to render the service. Contract liabilities are recognized initially at their fair value. Subsequent to initial recognition, advances from customers are measured at their amortised cost based on the projections of the services to be provided that cancel the advances, restated for the inflation effects as mentioned in Note 4.d).

Additionally, it includes the advance received by the UT from the Argentine Government as payment on account of the gas pipeline construction project. For more information, see “Note 23 - Associates and joint arrangements.”

4.r) Equity accounts

The activity in the Equity accounts reflects resolutions adopted by Shareholders in their meetings, or the effects of the laws or regulations in force. The equity accounts are restated for the inflation effects according to what is mentioned in Note 4.d), except the account Capital stock which is maintained at its original value.

Common stock and adjustment to common stock

The common stock consists of contributions made by shareholders represented by shares and comprises outstanding shares at their face value, net of treasury shares mentioned below.

Common stock accounts were restated in constant currency as mentioned in Note 4.d). Common stock account was kept at original value and the adjustment arising from such restatement is shown under “Inflation Adjustment to common stock”.

Common stock adjustment is not distributable in cash or in kind but may be capitalized through issuance of shares. In addition, this balance may be used to compensate accumulated losses.

Treasury shares and adjustments to treasury shares

Corresponds to the reclassification of the nominal value and corresponding restatement in constant peso (Inflation Adjustment to Common Stock) of shares issued and repurchased by the Company in market transactions, as required by the current regulations of the CNV.

Own equity instruments that are reacquired (treasury shares) are recognized at cost restated for the inflation effects as mentioned in Note 4.d), and deducted from equity. No gain or loss is recognized on the purchase, sale or cancellation of the Company’s treasury shares. Any difference between the carrying amount and the consideration, if reissued, is recognized as a premium on common stock or additional paid-up capital.

Additional paid-up capital

Corresponds to the difference between the carrying value of the treasury shares and the quoted value at the time were distributed (for more information see Note 19.b). It is restated according to what is mentioned in Note 4.d).

Legal Reserve

Pursuant to the provisions of the Argentine Business Association Law and the CNV, the Company is required to set up a legal reserve by providing at least 5% of the aggregate amount of net income for the year, prior year adjustments, transfers of other comprehensive income to retained earnings and accumulated losses of prior years, when this aggregate amount exceeds zero until the legal reserve equals 20% of the sum of Capital stock and Adjustment to capital stock balances.

Distribution of dividends

The cash dividend is recognized as a liability in the Company’s financial statements in the year in which they are approved by the shareholders of the Company or the Board of Directors according to the powers delegated by the Shareholders’ Meeting, as appropriate.

Retained earnings

The outstanding balance of retained earnings includes accumulated gains or losses which were not allocated to a specific purpose reserve and, when positive, may be distributed pursuant to the decision of the Shareholders provided these retained earnings are not subject to legal restrictions, as mentioned above “Legal reserve”.

4.s) Basic and diluted earnings per share

Earnings per share as of December 31, 2022, 2021 and 2020 were calculated as follows:

	2022		2021		2020
Net income attributable to owners of the Company		32,317,790		40,772,306		9,662,187
Average number of outstanding shares (1)		752,761,058		752,761,058		762,371,755
Basic and diluited earnings per share		42.93		54.16		12.68

⁽¹⁾ The weighted average number of shares considers the effect of the weighted average of the changes originated in the transactions with the treasury shares made during the year.

As of December 31, 2022, 2021 and 2020, there are no tgs instruments outstanding that imply the existence of potential ordinary shares, thus the basic net income per share for each of the three years ended on December 31, 2022, 2021 and 2020 matches the diluted net income per share.

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CRITICAL ACCOUNTING ESTIMATES AND JUDGMENTS

12 Months Ended

Dec. 31, 2022

CRITICAL ACCOUNTING ESTIMATES AND JUDGMENTS [Abstract]

CRITICAL ACCOUNTING ESTIMATES AND JUDGMENTS

5. CRITICAL ACCOUNTING ESTIMATES AND JUDGMENTS

The preparation of financial statements in conformity with professional accounting standards requires the Company to make accounting estimates that affect the reported amounts of assets and liabilities and the disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The making of such estimates involves tgs using assumptions and presumptions that are based on a number of factors, including past trends, events known at the date of issuance of these financial statements, and expectations of future events and their outcomes.

5.a) Impairment of PPE

As mentioned in Note 4.j), the management periodically evaluates the existence of significant events or changes that could have an adverse effect on the Company or will take place in the near future that could affect the recoverable amount of PPE. PPE is tested to assess whether an impairment or reversal of a previous impairment is required when significant changes took place during the period, or that will take place in the near future, indicate that the recoverable value of the PPE amounts may be affected. These evaluations are performed at the lowest level for which identifiable cash flows exist, i.e., for each CGU. The management considers each business segment as a CGU.

When assessing whether an impairment indicator may exist, tgs evaluates both internal and external sources of information, such as the following:

• Whether significant decreases in the market values of PPE elements took place.

• Whether prices of the main products and services that are marketed decreased.

• Whether significant changes in the regulatory framework were introduced.

• Whether operating costs suffered a materially increase.

• Whether evidence of obsolescence or physical damage has occurred.

• Whether the macroeconomic situation in which tgs carries out its activities, including significant variations in the sale prices of products, raw materials, interest rates, etc, has worsen.

Since August 2019, the main macroeconomic and business variables in Argentina suffered a significant deterioration. This situation was aggravated in 2020 by the negative consequences that COVID had on Argentina’s economic situation which led the Argentine Government to take a series of measures even affecting the regulatory framework of the natural gas transportation segment (see Notes 1 and 17). Given these indicators of impairment of the book value of PPE, the recoverable value of Natural Gas Transportation segment CGU has been calculated based on its value in use as of December 31, 2022.

The value in use of PPE is sensitive to significant variation in the assumptions applied, including the determination of future tariffs determined by the Argentine Government in the Natural Gas Transportation segment.

The value in use is calculated based on the basis of discounted future cash flows. The projected cash flows are prepared taking into account significant assumptions relating to: discount rate, estimates of future tariff adjustments and the recognition of cost adjustments, and expected macroeconomic variables such as interest rates, inflation, foreign exchange rates, among others. The discount rate is based on a weighted average cost of capital (“WACC”).

In performing the analysis for the Natural Gas Transportation segment, the management considered among others: (i) the status of the negotiations with the Argentine Government, (ii) the contractual rights derived from the License, (iii) Management´s expectations with respect to the transitional tariff increase to be granted until the new RTI is finalized, (iv) Management´s expectation of the outcome of the new RTI process and (v) the impact of a cost monitoring scheme that allows for semi-annual adjustments to current tariffs.

The management has prepared, for the Natural Gas Transportation segment, three different estimates of the expected cash flows by sensitizing its main variables (as described above) and assigning probabilities of occurrence based on experience and considering the current socio-economic context, as follows:

a) Base scenario: probability of occurrence assigned 65%

b) Optimistic scenario: probability of occurrence assigned 20%.

c) Pessimistic scenario: probability of occurrence assigned  15%.

In order to make the comparison between the expected cash flow and the book value of the assets assigned to the Natural Gas Transportation segment, the Company has used a weighting of the scenarios, in accordance with the probabilities mentioned above, to determine the expected value in use.

As of December 31, 2022 and 2021, based on the foregoing, the management has not determined the need to record an additional impairment charge.

During 2020, we recorded an impairment of Ps. 9,155 million on our Natural Gas Transportation segment fixed assets as a consequence of the impairment test.

As of December 31, 2022, the Company’s book value of PPE related to Natural Gas Transportation cash-generating units amounted Ps. 189,314,745.

The estimated recoverable amounts of PPE items are sensitive to significant variation in the assumptions applied. In either case, there can be no assurance with certainty that the actual cash flows arising from these circumstances will be in line with the assumptions applied in determining the values in use. Therefore, significant differences could arise in the future in relation to the estimated values in use.

5.b) Provisions for legal and other claims

The Company has recorded certain contingent liabilities related to legal, judicial or extrajudicial actions, claims and administrative proceedings, including those of a legal and regulatory nature. The Company records liabilities when their occurrence is probable and when a reliable estimate of their amount can be made. Provisions are based on events known to the Company at the date of issuance of its financial statements, their probability of occurrence, its estimates of the outcome of such matters and the experience of its legal advisors in contesting, litigating and settling other matters. To the extent that there are more elements of judgment that allow improving the evaluation of contingencies, there will be changes in the estimates of future charges, which could have an impact on the Company’s future results and its economic and/or financial situation.

5.c) Income tax

Deferred tax assets are recognized for all tax loss carryforwards to the extent that it is probable that there will be a taxable profit against which the tax loss can be utilized. Determining the amount of deferred tax assets that can be recognized requires significant judgments to be made by management based on the likely timing and level of future tax benefits, together with future tax planning strategies and macroeconomic variables that impact the business.

On December 29, 2017, the PEN enacted and put into effect through Decree 1112/2017 a tax reform sanctioned in the National Congress through Law No. 27,430 (the “Tax Reform”) whereby a decrease in tax rates was determined. Subsequently, through the enactment of the Law of Social Solidarity and Productive Reactivation in the Framework of Public Emergency No. 27,541 (“Solidarity Law”), the Argentine Government defined the postponement of the reduction of the current tax rate for fiscal years beginning on or after January 1, 2021.

On June 16, 2021, “Law No. 27,630: Amending the Income Tax Law” was published in the Official Gazette which, among other issues, introduces a modification in the income tax rate effective for fiscal years or fiscal years beginning on or after January 1, 2021. The amendment establishes a tiered system of rates in three segments according to the level of accumulated net taxable income: a first step of 25% for accumulated net income up to $ 5 million pesos; the second step of 30% for accumulated net income between $ 5 and $ 50 million pesos; and a last segment of 35% for accumulated net income over $ 50 million pesos. The amount of accumulated net profits will be adjusted annually, starting January 1, 2022, considering the annual variation of the CPI provided by INDEC.

For the determination of the deferred and current income tax charge as of December 31, 2022 and 2021, the Company has applied the progressive tax rate in force as mentioned above.

More detailed information on income tax is included in Note 14 “Income tax and deferred income tax”.

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SUPPLEMENTAL CASH FLOW INFORMATION

12 Months Ended

Dec. 31, 2022

SUPPLEMENTAL CASH FLOW INFORMATION [Abstract]

SUPPLEMENTAL CASH FLOW INFORMATION

6. SUPPLEMENTAL CASH FLOW INFORMATION

For purposes of the consolidated statement of cash flows, the Company considers all highly liquid temporary investments with an original maturity of three months or less at the time of purchase to be cash equivalents. The Cash Flow Statement has been prepared using the indirect method, which requires a series of adjustments to reconcile net income for the period to net cash flows from operating activities.

Non-cash investing and financing activities for the years ended December 31, 2022, 2021 and 2020 are presented below:

	2022		2021		2020
Unpaid acquisition of PPE		1,846,947		1,856,040		895,394
Principal payment of financial lease (1)		901,526		1,163,922		561,495

⁽¹⁾ Cancelled through compensation with trade receivables with the creditor. See Note 13.

Note 13 to these consolidated financial statements includes a reconciliation between the initial and final balance of the financial liabilities arising from financing activities.

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CONSOLIDATED BUSINESS SEGMENT INFORMATION

12 Months Ended

Dec. 31, 2022

CONSOLIDATED BUSINESS SEGMENT INFORMATION [Abstract]

CONSOLIDATED BUSINESS SEGMENT INFORMATION

7. CONSOLIDATED BUSINESS SEGMENT INFORMATION

IFRS 8 “Operating Segments” requires an entity to report financial and descriptive information about its reportable segments, which are operating segments or aggregations of operating segments that meet specified criteria. Operating segments are components of an entity about which separate financial information is available that is evaluated regularly by the CODM in deciding how to allocate resources and in assessing performance. The Company’s CODM is the Board of Directors.

The Company analyzes its businesses into four segments: (i) Natural Gas Transportation Services, subject to ENARGAS regulations, (ii) Liquids Production and Commercialization, (iii) Other Services including midstream, among others, and (iv) Telecommunications. These last three business segments are not regulated by ENARGAS. Production and Commercialization of Liquids segment is regulated by the SE.

Detailed information on each business segment for the years ended December 31, 2022, 2021 and 2020 is disclosed below:

Year ended December 31, 2022
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenues from sales		40,643,462			104,214,859			18,747,054			919,414			-			164,524,789
Intersegment revenues		1,164,760			-			-			-			(1,164,760	)		-
Cost of sales		(29,357,094	)		(58,784,800	)		(8,407,580	)		(656,850	)		1,164,760			(96,041,564	)
Administrative expenses		(4,230,811	)		(829,258	)		(627,243	)		(67,121	)		-			(5,754,433	)
Selling expenses		(3,019,249	)		(5,737,983	)		(1,336,806	)		(109,559	)		-			(10,203,597	)
Other operating results		(180,352	)		37,940			65,914			-			-			(76,498	)
Operating profit		5,020,716			38,900,758			8,441,339			85,884			-			52,448,697
Depreciation of property, plant and equipment		(14,385,464	)		(1,308,511	)		(3,878,694	)		-			-			(19,572,669	)

	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		224,390,925		79,765,071		102,867,810		5,068,419		412,092,225
Identifiable liabilities		68,642,296		7,941,685		63,768,842		4,515,113		144,867,936

Year ended December 31, 2021
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenue from sales		47,729,944			108,559,750			16,137,635			892,492			-			173,319,821
Intersegment revenues		1,753,852			-			-			-			(1,753,852	)		-
Cost of sales		(30,398,565	)		(56,280,587	)		(7,294,631	)		(623,473	)		1,753,852			(92,843,404	)
Administrative expenses		(3,820,247	)		(664,124	)		(465,910	)		(45,786	)		-			(4,996,067	)
Selling expenses		(3,353,756	)		(4,889,198	)		(1,010,116	)		(86,494	)		-			(9,339,564	)
Other operating results		(396,796	)		626,862			20,099			760			-			250,925
Operating profit		11,514,432			47,352,703			7,387,077			137,499			-			66,391,711
Depreciation of property, plant and equipment		(13,844,172	)		(1,194,842	)		(3,682,135	)		-			-			(18,721,149	)

			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		242,560,322		74,892,859		87,327,237		739,498		405,519,916
Identifiable liabilities		78,050,198		21,404,091		70,954,650		204,490		170,613,429

Year ended December 31, 2020
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenue from sales		69,100,376			81,140,913			12,832,687			1,201,467			-			164,275,443
Intersegment revenues		2,483,327			-			-			-			(2,483,327	)		-
Cost of sales		(29,218,827	)		(46,554,104	)		(6,938,313	)		(821,874	)		2,483,327			(81,049,791	)
Administrative expenses		(3,652,010	)		(746,192	)		(512,372	)		(37,239	)		-			(4,947,813	)
Selling expenses		(4,290,739	)		(3,457,748	)		(881,361	)		(96,031	)		-			(8,725,879	)
Other operating (expenses) / income		(129,779	)		411,530			7,383			4,388			-			293,522
Impairment of PPE		(9,156,072	)		-			-			-			-			(9,156,072	)
Operating profit		25,136,276			30,794,399			4,508,024			250,711			-			60,689,410
Depreciation of property, plant and equipment		(13,415,586	)		(1,125,453	)		(3,574,463	)		-			-			(18,115,502	)

			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		243,316,895		52,023,450		82,037,118		720,848		378,098,311
Identifiable liabilities		81,196,369		15,989,754		86,567,711		210,291		183,964,125

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS

12 Months Ended

Dec. 31, 2022

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS [Abstract]

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS

8. DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS

a) Other receivables

	2022				2021
	Current		Non Current		Current		Non Current
Turnover tax balance		220,927		-		246,803		-
Income tax credit balance		96,687		-		42,697		-
VAT credit balance		1,495,500		-		1,368,925		-
Other tax receivables		107,249		55		73,562		919
Prepaid expenses		1,524,421		-		814,670		-
Advances to suppliers		8,338,576		-		5,887,123		-
Subsidies receivables		3,768,159		-		2,427,450		-
Other Receivables UT		33,460		-		56,924		-
Others		591,659		14,844		724,109		16,330
Total		16,176,638		14,899		11,642,263		17,249

b) Trade receivables

	2022					2021
	Current			Non Current		Current			Non Current
Commons		15,741,345			-		20,256,312			-
UT		9,448			-		205,075			-
Natural Gas Transportation		4,398,150			-		6,681,903			-
Production and Commercialization of Liquids		8,189,884			-		10,793,068			-
Other services		3,143,863			-		2,576,266			-
Related parties (Note 21)		1,330,471			-		695,684			-
Natural Gas Transportation		131,145			-		158,708			-
Production and Commercialization of Liquids		281,774			-		210			-
Other services		917,552			-		536,766			-
Allowance for doubtful accounts		(132,521	)		-		(258,142	)		-
Total		16,939,295			-		20,693,854			-

The movement of the allowance for doubtful accounts is as follows:

Balances as of December 31, 2020	389,643
Inflation adjustment restatement	(131,501	)
Additions	-
Applications	-
Reversals	-
Balances as of December 31, 2021	258,142
Inflation adjustment restatement	(125,621	)
Additions	-
Applications	-
Reversals	-
Balances as of December 31, 2022	132,521

c) Cash and cash equivalents

	2022		2021
Cash and banks		289,630		213,984
UT Cash and banks		159		142
Mutual funds in local currency		2,654,934		8,138,623
Interest-bearing accounts		33,343		214,906
UT Mutual funds		10,880		59,349
Total		2,988,946		8,627,004

d) Contract liabilities

	2022				2021
	Current		Non Current		Current		Non Current
Natural Gas Transportation		360,887		5,902,032		360,886		6,262,944
Production and Commercialization of Liquids		345,243		557,671		263,596		902,915
Other services		326,802		5,257,709		327,971		3,797,298
UT		12,522		-		26,122		-
Total		1,045,454		11,717,412		978,575		10,963,157

During 2022 and 2021 financial years, the Company recognized Ps. 469,978 and Ps. 477,516, respectively, in revenues for sales from contracts with clients in the Statement of Comprehensive Income, which had been included in the balance at the beginning of each year.

Revenues related to the contract liabilities will be recognized in the Statement of Comprehensive Income in accordance with the schedule stipulated with the customers for the provision of the service, which will be completed between 2025 and 2053.

e) Other payables

	2022				2021
	Current		Non Current		Current		Non Current
Payable for compensation for the Board of Directors and Supervisory Committee		68,039		-		37,809		-
Others		1,763		-		1,983		-
UT Other liabilities		216,753		-		580,178		-
Total		286,555		-		619,970		-

f) Taxes payables

	2022				2021
	Current		Non Current		Current		Non Current
Health and safety tax		52,339		-		41,921		-
Withholdings and perceptions made to third parties		581,800		-		621,114		-
Turnover Tax		158,382		-		267,965		-
Tax on exports		103,759		-		337,941		-
Others		48,416		14,285		28,485		-
Total		944,696		14,285		1,297,426		-

g) Trade payables

	2022				2021
	Current		Non Current		Current		Non Current
Suppliers		9,717,662		-		10,662,184		-
UT Suppliers		119,077		-		129,333		-
Customers (credit balances)		15,237		-		18,778		-
Related companies (Note 21)		672,960		-		1,010,388		-
Total		10,524,936		-		11,820,683		-

h) Revenues

	2022		2021		2020
Sales of goods and services		159,116,112		169,132,295		163,311,441
Subsidies		5,408,677		4,187,526		964,002
Total		164,524,789		173,319,821		164,275,443

Disaggregation of revenues

Below is a table in which revenues are disaggregated considering the type of market and the opportunity to satisfy performance obligations:

Year ended December 31, 2022
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		46,313,662		-		-		46,313,662
Local market		40,643,462		57,901,197		18,747,054		919,414		118,211,127
Total		40,643,462		104,214,859		18,747,054		919,414		164,524,789
Timing of revenue recognition:
Over the time		40,643,462		4,504,128		18,747,054		919,414		64,814,058
At a point in time		-		99,710,731		-		-		99,710,731
Total		40,643,462		104,214,859		18,747,054		919,414		164,524,789

Year ended December 31, 2021
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		44,708,635		-		-		44,708,635
Local market		47,729,944		63,851,115		16,137,635		892,492		128,611,186
Total		47,729,944		108,559,750		16,137,635		892,492		173,319,821
Timing of revenue recognition:
Over the time		47,729,944		4,786,166		16,137,635		892,492		69,546,237
At a point in time		-		103,773,584		-		-		103,773,584
Total		47,729,944		108,559,750		16,137,635		892,492		173,319,821

Year ended December 31, 2020
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		28,033,885		-		-		28,033,885
Local market		69,100,376		53,107,028		12,832,687		1,201,467		136,241,558
Total		69,100,376		81,140,913		12,832,687		1,201,467		164,275,443
Timing of revenue recognition:
Over the time		69,100,376		4,898,351		12,832,687		1,201,467		88,032,881
At a point in time		-		76,242,562		-		-		76,242,562
Total		69,100,376		81,140,913		12,832,687		1,201,467		164,275,443

Detailed information of revenues on each business segment for the years ended December 31, 2022, 2021 and 2020 is disclosed below:

i. Natural Gas Transportation:

	2022		2021		2020
Firm		33,984,311		38,806,353		56,118,114
Access and Charge		1,409,911		1,680,113		2,469,413
Interruptible and Others		5,249,240		7,243,478		10,512,849
Total		40,643,462		47,729,944		69,100,376

ii. Production and Commercialization of Liquids:

	2022		2021		2020
Product		94,302,054		99,586,058		75,278,560
Services		4,504,128		4,786,166		4,898,351
Government grants		5,408,677		4,187,526		964,002
Total		104,214,859		108,559,750		81,140,913

iii. Other services:

	2022		2021		2020
Conditioning and treatment		5,941,496		6,509,010		5,989,222
Operation and maintenance		450,840		481,338		490,937
Steam sales		372,779		429,014		535,488
Construction		2,363		87,610		75,893
UT Construction		43,537		79,694		207,231
Transportation and conditioning of Natural Gas		11,717,321		8,137,078		5,274,364
Others		218,718		413,891		259,552
Total		18,747,054		16,137,635		12,832,687

i) Net cost of sales

	2022			2021			2020
Inventories at the beginning of the year		2,278,309			1,680,352			1,231,440
Purchases		48,129,536			46,041,630			37,255,612
Operating costs (Note 8.j.)		47,467,264			47,399,731			44,243,091
Inventories at the end of the year		(1,833,545	)		(2,278,309	)		(1,680,352	)
Total		96,041,564			92,843,404			81,049,791

j) Expenses by nature – Information required under art. 64 paragraph I, clause B) Commercial Companies Law

	2022
			Operating expenses
Accounts	Total		Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other compensations		13,296,943		5,584,104		4,529,381		2,438,849		744,609			-
Social security taxes		2,521,317		1,034,058		890,630		441,721		154,908			-
Compensation to Directors and Supervisory Committee		125,897		-		-		125,897		-			-
Professional services fees		1,644,291		48,972		600,631		898,431		96,257			-
Technical operator assistance fees		3,067,198		280,709		2,786,489		-		-			-
Materials		1,594,685		462,672		1,130,811		-		1,202			-
Third parties services		1,563,456		679,466		688,730		195,260		-			-
Telecommunications and post expenses		84,443		16,128		26,623		36,931		4,761			-
Rents		108,981		17,579		80,773		9,653		976			-
Transports and freight		613,856		349,132		252,357		11,993		374			-
Easements		200,955		156,726		44,229		-		-			-
Offices supplies		46,944		18,548		9,598		17,996		802			-
Travels expenses		198,078		102,338		35,091		46,229		14,420			-
Insurance		687,743		398,963		237,271		51,509		-			-
Property, plant and equipment maintenance		6,464,178		5,111,188		1,274,298		78,692		-			-
Depreciation of property, plant and equipment		19,572,669		13,185,736		5,187,205		1,199,728		-			-
Taxes and contributions		10,858,003		1,786,426		60,885		29,609		8,981,083	(1)		-
Advertising		189,091		-		-		-		189,091			-
Banks expenses		99,346		-		-		99,346		-			-
Interests expense		6,798,475		-		-		-		-			6,798,475
Foreign exchange loss		52,105,975		-		-		-		-			52,105,975
Costs of services rendered to third parties		48,922		-		48,922		-		-			-
Other expenses		438,298		124,348		226,247		72,589		15,114			-
Total 2022		122,329,744		29,357,093		18,110,171		5,754,433		10,203,597			58,904,450

⁽¹⁾ Includes tax on exports for Ps. 3,659,451 for the year ended December 31, 2022.

	2021
				Operating expenses
Accounts	Total			Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other contributions		11,614,557			5,027,119		3,883,677		2,072,132		631,629			-
Social security taxes		2,355,744			1,047,791		820,929		341,671		145,353			-
Compensation to Directors and Supervisory Committee		124,190			-		-		124,190		-			-
Professional services fees		996,024			70,276		103,990		781,403		40,355			-
Technical operator assistance fees		4,250,358			744,106		3,506,252		-		-			-
Materials		1,601,348			531,421		1,069,880		-		47			-
Third parties services		1,414,519			662,460		673,542		78,517		-			-
Telecommunications and post expenses		94,968			18,745		18,309		48,768		9,146			-
Rents		61,124			28,263		16,423		15,554		884			-
Transports and freight		496,898			287,470		201,379		7,712		337			-
Easements		355,420			334,008		21,412		-		-			-
Offices supplies		38,629			13,620		8,481		14,812		1,716			-
Travels expenses		109,433			60,943		21,137		22,368		4,985			-
Insurance		852,181			495,149		298,049		58,983		-			-
Property, plant and equipment maintenance		7,814,946			6,598,364		1,134,931		81,651		-			-
Depreciation of property, plant and equipment		18,721,149			12,564,973		4,876,977		1,279,199		-			-
Taxes and contributions		10,433,607			1,809,784		74,808		32,406		8,516,609	(1)		-
Advertising		103,548			-		-		-		103,548			-
Doubtful accounts		(129,715	)		-		-		-		(129,715	)		-
Banks expenses		23,340			-		-		23,340		-			-
Interests expense		8,703,402			-		-		-		-			8,703,402
Foreign exchange loss		24,239,337			-		-		-		-			24,239,337
Costs of services rendered to third parties		111,952			-		111,952		-		-			-
Other expenses		291,142			104,070		159,041		13,361		14,670			-
Total 2021		94,678,101			30,398,562		17,001,169		4,996,067		9,339,564			32,942,739

⁽¹⁾ Includes tax on exports of Ps. 3,069,765 for the year ended December 31, 2021.

	2020
			Operating expenses
Accounts	Total		Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other compensations		11,910,337		5,332,943		3,720,628		2,180,423		676,343			-
Social security taxes		2,422,583		1,044,064		744,398		487,600		146,521			-
Compensation to Directors and Supervisory Committee		117,725		-		-		117,725		-			-
Professional services fees		929,950		101,483		39,103		708,924		80,440			-
Technical operator assistance fees		4,205,901		1,733,124		2,472,777		-		-			-
Materials		1,332,039		482,988		849,051		-		-			-
Third parties services		1,523,368		692,579		772,421		56,718		1,650			-
Telecommunications and post expenses		139,427		39,218		30,941		61,112		8,156			-
Rents		74,086		29,685		15,245		26,924		2,232			-
Transports and freight		460,821		273,192		180,073		7,556		-			-
Easements		289,449		257,489		31,960		-		-			-
Offices supplies		26,629		9,077		3,787		12,962		803			-
Travels expenses		200,878		90,310		58,722		44,430		7,416			-
Insurance		752,400		431,938		267,609		52,812		41			-
Property, plant and equipment maintenance		5,505,454		4,733,387		676,821		95,246		-			-
Depreciation of property, plant and equipment		18,115,502		12,414,245		4,699,917		1,001,340		-			-
Taxes and contributions		8,830,693		1,487,002		76,682		3,758		7,263,251	(1)		-
Advertising		252,851		-		-		-		252,851			-
Doubtful accounts		279,520		-		-		-		279,520			-
Banks expenses		69,783		-		-		69,783		-			-
Interests expense		9,874,146		-		-		-		-			9,874,146
Foreign exchange loss		43,621,645		-		-		-		-			43,621,645
Costs of services rendered to third parties		319,508		-		319,508		-		-			-
Other expenses		157,879		66,103		64,621		20,500		6,655			-
Total 2020		111,412,574		29,218,827		15,024,264		4,947,813		8,725,879			53,495,791

⁽¹⁾ Includes tax on exports for Ps. 1,238,347 for the year ended December 31, 2020.

k) Net financial results

	2022			2021			2020
Financial income
Interest income		1,834,401			1,543,011			1,607,135
Foreign exchange gain		27,942,306			11,843,541			14,609,528
Subtotal		29,776,707			13,386,552			16,216,663
Financial expenses
Interest expense (1)		(6,798,475	)		(8,703,402	)		(9,874,146	)
Foreign exchange loss		(52,105,975	)		(24,239,337	)		(43,621,645	)
Subtotal		(58,904,450	)		(32,942,739	)		(53,495,791	)
Other financial results
Notes repurchase results		(1,030,169	)		(806,841	)		1,174,202
Derivative financial instruments results		(127,585	)		(157,227	)		1,321,859
Fair value gains / (losses) on financial instruments through profit or loss		24,127,905			2,319,880			(21,362,711	)
Others		(770,571	)		(960,662	)		(1,052,827	)
Subtotal		22,199,580			395,150			(19,919,477	)
Gain on net monetary position		3,768,283			18,311,140			19,058,813
Total		(3,159,880	)		(849,897	)		(38,139,792	)

⁽¹⁾ Includes Ps. 382,649, Ps. 568,315 and Ps. 712,528 of accrued interest corresponding to leasing liabilities, for the years ended December 31, 2022, 2021 and 2020.

l) Other operating results

	2022			2021			2020
Net increase in provisions (1)		(356,890	)		(612,036	)		(453,946	)
Recovery of insurance		29,000			730,846			696,771
Recovery action of VAT and income tax (Note 20.c)		-			144,912			-
Others		251,392			(12,797	)		50,697
Total		(76,498	)		250,925			293,522

⁽¹⁾ Including legal expenses

m) Financial assets measured at amortized cost

	2022				2021
	Current		Non Current		Current		Non Current
Fixed term deposits in foreign currency		-		39,290,345		-		43,718,093
VRD bonds		1,438		-		3,721		2,306
Private debt bonds		-		871,938		-		-
Total		1,438		40,162,283		3,721		43,720,399

n) Financial assets at fair value through profit or loss

	2022				2021
	Current		Non Current		Current		Non Current
Mutual funds in local market		-		-		152,868		-
Public debt bonds		7,162,504		-		6,432,817		-
Private debt bonds with related parties		2,570,796		-		1,388,558		-
Private debt bonds		25,808,410		-		17,870,749		-
Equity instruments		3,747,920		-		-		-
Total		39,289,630		-		25,844,992		-

o) Payroll and social security taxes payable

	2022				2021
	Current		Non Current		Current		Non Current
Vacation benefit payable		1,296,356		-		1,186,142		-
Annual bonus payable		857,151		-		896,347		-
Social security taxes payable		471,945		-		685,123		-
UT		4,377		-		6,957		-
Total		2,629,829		-		2,774,569		-

XML

INVESTMENTS IN ASSOCIATES

12 Months Ended

Dec. 31, 2022

INVESTMENTS IN ASSOCIATES [Abstract]

INVESTMENTS IN ASSOCIATES

9. INVESTMENTS IN ASSOCIATES

	2022						2021
	Description of securities
	Face		Amount		Book value		Book value
Name and issuer	value
Transporte y Servicios de Gas en Uruguay S.A.	Ps. Uru. 1			196,000		13,502		19,339
Emprendimientos de Gas del Sur S.A. (in liquidation)	$	1		116,130		700		1,132
Gas Link S.A.	$	1		502,962		140,300		43,900
Total						154,502		64,371

XML

JOINT ARRANGEMENTS

12 Months Ended

Dec. 31, 2022

JOINT ARRANGEMENTS [Abstract]

JOINT ARRANGEMENTS

10. JOINT ARRANGEMENTS

tgs jointly with SACDE applied for the public tender launched by the Argentine Government for the construction of a connection pipeline in the province of Santa Fe. This tender was finally obtained by the UT whose sole purpose is the execution of such works. For further information, see Note 23.

The Company participates in the UT in a percentage of 51% on the rights of the assets and on the obligations related to them. tgs consolidates line by line assets, liabilities and results of the UT based on the aforementioned percentage of participation.

The breakdown of the amounts included in the statements of financial position related to the Company’s participation in the UT and its results is the following:

	2022		2021
Consolidated Statements of financial position
Non Current assets		-		-
Current Assets		72,020		368,325
Total		72,020		368,325
Non Current Liabilities		-		-
Current Liabilities		278,622		739,043
Total		278,622		739,043

	2022			2021			2020
Consolidated Statements of comprehensive income
Gross profit		27			53			13,415
Operating loss		(7,854	)		(15,299	)		(3,719	)
Net Financial results		141,140			274,931			220,157
Comprehensive income		133,286			259,632			216,438

XML

SHARE OF PROFIT FROM ASSOCIATES

12 Months Ended

Dec. 31, 2022

SHARE OF PROFIT FROM ASSOCIATES [Abstract]

SHARE OF PROFIT FROM ASSOCIATES

11. SHARE OF PROFIT FROM ASSOCIATES

	2022			2021			2020
EGS (in liquidation)		(432	)		(308	)		(232	)
TGU		(5,837	)		(5,770	)		(1,418	)
Link		96,407			47,425			64,307
Total		90,138			41,347			62,657

XML

PROPERTY, PLANT AND EQUIPMENT

12 Months Ended

Dec. 31, 2022

PROPERTY, PLANT AND EQUIPMENT [Abstract]

PROPERTY, PLANT AND EQUIPMENT

12. PROPERTY, PLANT AND EQUIPMENT

	2022
	Cost												Depreciation and Impairment
													Accumulated at									Accumulated at
	Beginning										End of the		the beginning									the end		Net
Account	of the year		Additions		Retirements			Transfers			year		of the year		Retirements			For the year		rate %		of the year		book value
Pipelines		265,066,631		-		-			4,361,804			269,428,435		144,855,499		-			6,548,184		2.2		151,403,683		118,024,752
Compressor plants		116,840,361		-		-			4,135,224			120,975,585		80,652,592		-			5,284,061	3.3 to 25			85,936,653		35,038,932
Other plants		106,030		-		-			-			106,030		46,113		-			3,289		3.3		49,402		56,628
Stations of regulation and/or measurement of pressure		9,502,577		-		-			165,914			9,668,491		7,489,062		-			260,160		4.0		7,749,222		1,919,269
Other technical installations		1,964,446		-		-			420,266			2,384,712		1,542,316		-			73,079		6.7		1,615,395		769,317
Subtotal assets related to natural gas transportation service		393,480,045		-		-			9,083,208			402,563,253		234,585,582		-			12,168,773				246,754,355		155,808,898
Non-regulated segment Pipelines		43,520,177		-		-			185,982			43,706,159		3,383,838		-			1,444,820		2.2		4,828,658		38,877,501
Non-regulated segment Compressor plants		8,422,007		-		-			72,584			8,494,591		4,969,891		-			870,535	3.3 to 25			5,840,426		2,654,165
Non-regulated segment Other plants		77,586,306		-		(1,863,128	)		10,121,226			85,844,404		44,982,655		(1,863,128	)		2,220,735		3.3		45,340,262		40,504,142
Non-regulated segment Stations of regulation and/or measurement of pressure		2,829,148		-		-			3,603			2,832,751		384,512		-			111,187		4.0		495,699		2,337,052
Non-regulated segment Other technical installations		1,040,891		-		-			47,379			1,088,270		577,826		-			90,090		6.7		667,916		420,354
Subtotal assets related to Other Services and Production and Commercialization of Liquids		133,398,529		-		(1,863,128	)		10,430,774			141,966,175		54,298,722		(1,863,128	)		4,737,367				57,172,961		84,793,214
Lands		1,417,568		-		-			-			1,417,568		-		-			-		-		-		1,417,568
Buildings and constructions		15,604,574		-		-			372,507			15,977,081		7,887,429		-			308,816		2.0		8,196,245		7,780,836
Facilities and features in building		1,157,039		-		-			20,995			1,178,034		526,674		-			35,163		4.0		561,837		616,197
Machinery, equipment and tools		5,353,477		237,299		-			28,117			5,618,893		3,461,019		-			554,096	6.7 to 10			4,015,115		1,603,778
UT Machinery, equipment and tools		3,641		-		-			-			3,641		3,641		-			-	6.7 to 10			3,641		-
Computers and Telecommunication systems		22,870,210		-		-			1,458,548			24,328,758		17,579,964		-			1,577,198	6.7 to 20			19,157,162		5,171,596
Vehicles		2,221,358		159,632		-			-			2,380,990		1,721,854		-			182,037		20		1,903,891		477,099
Furniture		955,440		7,472		-			41			962,953		902,025		-			9,219		10		911,244		51,709
Materials		15,791,047		6,275,734		(96,242	)		(5,242,745	)		16,727,794		-		-			-		-		-		16,727,794
Line pack		2,133,003		-		-			-			2,133,003		110,662		-			-		-		110,662		2,022,341
Works in progress		19,226,284		14,933,727		-			(16,151,445	)		18,008,566		-		-			-		-		-		18,008,566
Total		613,612,215		21,613,864		(1,959,370	)		-			633,266,709		321,077,572		(1,863,128	)		19,572,669				338,787,113		294,479,596

	2021
	Cost												Depreciation and Impairment
													Accumulated at									Accumulated at
	Beginning										End of the		the beginning									the end		Net
Account	of the year		Additions		Retirements			Transfers			year		of the year		Retirements			For the year		rate %		of the year		book value
Pipelines		263,565,765		-		(586	)		1,501,452			265,066,631		138,428,020		(341	)		6,427,820		2.2		144,855,499		120,211,132
Compressor plants		112,497,073		-		(74	)		4,343,362			116,840,361		75,761,325		(70	)		4,891,337		3.3 a 25		80,652,592		36,187,769
Other plants		106,030		-		-			-			106,030		42,726		-			3,387		3.3		46,113		59,917
Stations of regulation and/or measurement of pressure		8,933,021		-		-			569,556			9,502,577		7,240,802		-			248,260		4.0		7,489,062		2,013,515
Other technical installations		1,701,491		-		-			262,955			1,964,446		1,499,144		-			43,172		6.7		1,542,316		422,130
Subtotal assets related to natural gas transportation service		386,803,380		-		(660	)		6,677,325			393,480,045		222,972,017		(411	)		11,613,976				234,585,582		158,894,463
Non-regulated segment Pipelines		43,383,354		-		-			136,823			43,520,177		1,942,152		-			1,441,686		2.2		3,383,838		40,136,339
Non-regulated segment Compressor plants		8,361,565		-		-			60,442			8,422,007		4,093,187		-			876,704		3.3 a 25		4,969,891		3,452,116
Non-regulated segment Other plants		75,790,110		-		-			1,796,196			77,586,306		43,017,260		-			1,965,395		3.3		44,982,655		32,603,651
Non-regulated segment Stations of regulation and/or measurement of pressure		2,616,454		2,643		-			210,051			2,829,148		275,237		-			109,275		4.0		384,512		2,444,636
Non-regulated segment Other technical installations		1,016,791		-		-			24,100			1,040,891		485,393		-			92,433		6.7		577,826		463,065
Subtotal assets related to Other Services and Production and Commercialization of Liquids		131,168,274		2,643		-			2,227,612			133,398,529		49,813,229		-			4,485,493				54,298,722		79,099,807
Lands		1,417,568		-		-			-			1,417,568		-		-			-		-		-		1,417,568
Buildings and constructions		14,995,664		-		(12	)		608,922			15,604,574		7,588,478		(10	)		298,961		2.0		7,887,429		7,717,145
Facilities and features in building		1,055,941		-		(39	)		101,137			1,157,039		495,969		(37	)		30,742		4.0		526,674		630,365
Machinery, equipment and tools		4,687,684		425,882		-			239,911			5,353,477		2,999,073		-			461,946		6.7 a 10		3,461,019		1,892,458
UT Machinery, equipment and tools		3,641		-		-			-			3,641		3,641		-			-		6.7 a 10		3,641		-
Computers and Telecommunication systems		21,180,182		-		-			1,690,028			22,870,210		15,932,596		-			1,647,368		6.7 a 20		17,579,964		5,290,246
Vehicles		2,070,127		153,637		(2,406	)		-			2,221,358		1,547,470		(2,001	)		176,385		20.0		1,721,854		499,504
Furniture		918,308		37,054		-			78			955,440		895,747		-			6,278		10.0		902,025		53,415
Materials		13,940,845		6,478,730		(125,178	)		(4,503,350	)		15,791,047		-		-			-		-		-		15,791,047
Line pack		2,133,003		-		-			-			2,133,003		110,662		-			-		-		110,662		2,022,341
Works in progress		12,695,872		13,572,075		-			(7,041,663	)		19,226,284		-		-			-		-		-		19,226,284
Total		593,070,489		20,670,021		(128,295	)		-			613,612,215		302,358,882		(2,459	)		18,721,149				321,077,572		292,534,643

The following is the composition of the resulting net book value of Property, plant and equipment as of December 31, 2022 and 2021:

	2022			2021
Cost		633,266,709			613,612,215
Accumulated depreciaton		(338,787,113	)		(321,077,572	)
Total		294,479,596			292,534,643

As of December 31, 2022 and 2021, the assets related to the Other Services and Production and Commercialization of Liquids segments contains the following assets for right of use:

	2022		2021
Other plants		986,979		1,256,155
Compressor plants		2,450,404		3,118,695
Other technical installations		278,631		354,621
Total		3,716,014		4,729,471

The book value variation of the rights-of use accounted during the years ended on December 31, 2022 and 2021 corresponds to its depreciation:

	2022			2021
Other plants		(269,176	)		(269,177	)
Compressor plants		(668,291	)		(668,293	)
Other technical installations		(75,990	)		(75,989	)
Total		(1,013,457	)		(1,013,459	)

The right to use these assets expires in September 2026, at which time the purchase options provided for in the contracts may be exercised.

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LOANS

12 Months Ended

Dec. 31, 2022

LOANS [Abstract]

LOANS

13. LOANS

Short-term and long-term loans as of December 31, 2022 and 2021 comprise the following:

	2022		2021
Current Loans
2018 Notes Interest		937,379		1,075,060
Bank loans		1,440,989		-
Other financial liabilities		377,415		-
Leasing (Note 21)		1,164,146		1,224,678
Total Current loans		3,919,929		2,299,738
Non Current Loans
2018 Notes		83,292,496		95,458,303
Leasing (Note 21)		3,098,069		4,662,971
Bank loans		4,303,571		-
Total non current loans		90,694,136		100,121,274
Total (1)		94,614,065		102,421,012

⁽¹⁾ As of December 31, 2022 and 2021, it is net of Notes repurchase of Ps 5,257,400 and Ps. 4,484,852, respectively.

⁽²⁾ Net of issuance expenses of Ps. 30,105 and Ps. 102,623 as of December 31, 2022 and 2021, respectively.

Loans are totally denominated in US dollars.

The activity of the loans as of December 31, 2022 and 2021 is the following:

	2022						2021
	Leases liabilities			Other payables			Leases liabilities			Other payables
Beginning balance		5,887,649			96,533,363			8,505,178			120,481,460
Inflation adjustment restatement		(4,769,942	)		(58,645,278	)		(3,164,211	)		(44,998,198	)
Accrued interest		382,649			5,875,804			568,315			7,321,812
Effect of foreign exchange effect		4,005,769			47,656,779			1,730,223			22,095,210
VAT unpaid installments		23,182			-			26,212			-
Proceeds from loans		-			6,164,853			-			-
Acquisition of notes result		-			1,030,169			-			806,841
Payment of loans(1)		(901,526	)		(86,187	)		(1,163,922	)		-
Acquisition of notes		-			(2,452,516	)		-			(1,869,224	)
Interest paid(2)		(365,566	)		(5,725,137	)		(614,146	)		(7,304,538	)
Ending balance		4,262,215			90,351,850			5,887,649			96,533,363

⁽¹⁾ For the years ended on December 31, 2022 and 2021, Ps. 901,526 and Ps. 1,163,922 respectively were cancelled through the offseting of debit balances maintained with the creditor (Pampa Energía).

⁽²⁾ For the years ended on December 31, 2022 and 2021, Ps. 365,566 and Ps. 614,146, respectively, were cancelled through the offseting of debit balances maintained with the creditor (Pampa Energía).

The maturities of the current and non-current loans as of December 31, 2022 are as follows, not including issuance expenses:

			To due
	Due at 12/31/2022		From 1/01/2023 to 12/31/2023		From 1/01/2024 to 12/31/2024		From 1/01/2025 to 12/31/2025		From 1/01/2026 to 12/31/2026		From 1/01/2027 onwards		Total
2018 Notes		-		937,379		-		83,292,496		-		-		84,229,875
Financial Leasing		133,549		1,030,597		1,117,025		1,210,816		770,228		-		4,262,215
Other financial liabilities		-		377,415		-		-		-		-		377,415
Bank loans		-		1,440,989		4,303,571		-		-		-		5,744,560
Total		133,549		3,786,380		5,420,596		84,503,312		770,228		-		94,614,065

The following table sets reconciliation between the total of future minimum lease payments as of December 31, 2022, and their present book value:

	12/31/2022
As of 12/31/2023		1,458,705
From 1/01/2024 to 12/31/2024		1,325,334
From 1/01/2025 to 12/31/2025		1,325,334
From 1/01/2026 to 12/31/2026		791,728
From 1/01/2027 onwards		-
Total minimum future payments		4,901,101
Future financial charges on financial leases		(638,886	)
Book Value financial leases		4,262,215

As of December 31, 2022 and 2021, the Company and its controlled companies are in compliance with the covenants established in all of their financial debt.

Description of the indebtedness of the Company

Class 2 Notes (“2018 Notes”)

The Ordinary General Shareholders’ Meeting held on April 26, 2017, ordered the increase of up to US$ 700,000,000 (or its equivalent in other currencies) of the 2017 Program authorized by the CNV by Resolution No. 17,262 dated January 3, 2014, whose amount until the Shareholders´ Meeting was held was US$ 400,000,000 (the “2017 Program”).

On May 2, 2018, within the framework of the 2017 Program, the Company issued the 2018 Notes according to the following characteristics:

	2018 Notes
Amount in U.S.$	500,000,000
Interest Rate	6.75% annual
Issuance price	99.725%

	Scheduled payment date	Percentage of the principal to be paid
Amortization	May 2, 2025	100%
Frequency of interest payment	Semiannual, payable on May 2 and November 2 of each year.
Guarantor	None

The authorization for the public offering of the 2017 Program was granted by the CNV through Resolutions No. 17,262 and 18,938 dated January 3, 2014 and September 15, 2017, respectively. On October 31, 2018, through Disposition No. DI-2018-55-APN-GE#CNV, the CNV granted the extension of the 2017 Program until January 3, 2024.

The Ordinary General Shareholders´ Meeting held on August 15, 2019 decided to increase the 2017 Program from US$ 700 million to US$ 1,200 million. This increase was authorized by the CNV on October 9, 2019 through Resolution RESFC-2019-20486-APN-DIR # CNV.

Funds obtained by the Company are applied to:

i. The repurchase of the Class 1 Notes (the “2014 Notes”) for U.S.$ 86,511,165;

ii. the cancellation and total redemption of the 2014 Notes for U.S.$ 120,786,581;

iii. the balance of net funds to make investments in capital expenditures.

The value of the financial debt is based on its amortised cost calculated as cash flows discounted at an effective rate of 7.088%.

During 2022 and 2021, the Company repurchased its marketable debt for a nominal value of USD 29.7 million and USD 4.8 million for which it paid Ps. 2,452,516 and Ps. 1,869,224, respectively. These transactions generated a result of (Ps. 1,030,169) and (Ps. 806,841) respectively, recognized in the financial results of the Statement of Income.

Other financial liabilities

As of December 31, 2022, Other financial liabilities includes:

Currency	Amount (in thousands)		Interest rate		Expiration date
USD		1,797		5.75% - 7.75%	Between May and September 2023
Euros		284		3.05% - 3.85%	April / May 2023
USD		8,000		4.30%	August 2023

Bank loans

On March 31, 2022, the subsidiary Telcosur, took a loan for US$24 million. The main terms of said loan are:

Amount in US$		24.000.000
Interest rate	1.5% annual
Amortizacion date	January 25, 2024
Interest payment frequency	To the expiration
Guarantee	Fixed term in foreign currency (1)

⁽¹⁾ Included as “Non-current financial assets measured at amortised cost”.

Covenants

As of December 31, 2022, the Company has complied with a series of restrictions derived from its current financial agreements, which include, among others, those related to obtaining new loans, payment of dividends, granting of guarantees, disposal of certain assets and make certain transactions with related parties.

he Company may contract new debts under the following conditions, among others:

a. To the extent that after the new debt has been incurred (i) the consolidated coverage ratio (calculated as the quotient of the consolidated adjusted EBITDA -earnings before financial results, income tax, depreciation and amortization- and the consolidated interest expense) is equal or higher than 2.0:1; and (ii) the consolidated debt ratio (calculated as the quotient of the consolidated debt and the consolidated EBITDA) is equal to or lower than 3.75:1.

b. For the refinancing of the outstanding financial debt.

c. Originated by customer advances.

The Company may pay dividends under the following conditions: (i) the Company is not in default under 2018 Notes, and (ii) immediately after any dividend payment, the Company may incur new debts according to the provisions in point a. of the preceding paragraph.

Lease liability

Corresponds to the financing obtained for the acquisition of the corresponding assets to the treatment and compression plant located in the area of Río Neuquén. Said agreement was concluded on August 11, 2016 with Petrobras (currently Pampa Energía) and consists of the payment of 119 consecutive monthly installments of U.S.$ 623,457 without taxes and an option to purchase for the same amount payable at the end of the 120th month of the effectiveness of the contract.

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INCOME TAX AND DEFERRED TAX

12 Months Ended

Dec. 31, 2022

INCOME TAX AND DEFERRED TAX [Abstract]

INCOME TAX AND DEFERRED TAX

14. INCOME TAX AND DEFERRED TAX

Tax Reform

The Tax Reform sanctioned in Argentina in 2017, with some amendments introduced in December 2018 after the issuance of Law No. 27,468, brought with it a series of modifications in the taxation and calculation of the income tax to which the Company is subject in the normal course of its activities. Subsequently, on the occasion of the enactment of the Solidarity Law, new modifications were introduced with impact as of the fiscal year beginning on January 1, 2019. The main changes are the following:

Applicable rate

Until the fiscal year ended on December 31, 2017, the income tax rate remained at 35%. The tax reform establishes a gradual reduction of the applicable rate for the calculation of income tax, being 30% and 25% for fiscal periods beginning on January 1, 2018 and 2019 and January 1, 2020 onwards, respectively.

The reduction in the applicable rate is complemented by the application of a tax on the distribution of dividends made to human persons and foreign beneficiaries, which the Company must withhold and enter the Tax authority as a single and definitive payment when the dividends are paid. This additional tax will be 7% or 13%, depending on whether the dividends distributed correspond to earnings of a fiscal period in which the Company was reached at the rate of 30% or 25%, respectively.

Solidarity Law suspended until fiscal years starting from 1st January 2021 inclusive, reduced to 25% of the applicable rate and retention of 13% on dividends.

On June 16, 2021, “Law No. 27,630: Amending the Income Tax Law” was published in the Official Gazette, which, among other issues, introduces a modification in the income tax rate effective for the years fiscal or fiscal years beginning on or after January 1, 2021 inclusive. The amendment establishes a tiered system of rates in three segments ( 25%, 30% and 35%) according to the level of accumulated net taxable income, which will be updated.

Likewise, dividends distributed to foreign individuals and beneficiaries will be taxed at a rate of 7%.

For the determination of the deferred and current income tax charge as of December 31, 2022 and 2021, the Company has applied the current progressive tax rate according to the scale updated by AFIP Resolution No. 5168/2022 of March 15, 2022.

Tax adjustment for inflation

Law No. 27,468 establishes that in the net taxable income of the periods beginning on or after January 1, 2018, the adjustment for inflation obtained by the application of the income tax law may be deducted or incorporated into the tax result for the fiscal year. This adjustment will proceed only if the percentage variation in the IPC, will accumulate (a) a percentage higher than 100% in the 36 months prior to the end of the year, or (b) regarding the first, second and third fiscal year that starts from its effective date, an accumulated variation of the IPC that exceeds 55%, 30% or 15% of said 100%, respectively.

For the fiscal year ended December 31, 2022 and 2021, the CPI has exceeded the 100% threshold mentioned above, so the Company has measured the tax charge to earnings for the year ended December 31, 2022 and 2021 considering the application of the adjustment for fiscal inflation.

According to the Solidarity Law, the positive or negative result generated by the application of the inflation adjustment corresponding to the first and second fiscal year beginning on January 1, 2019 will be charged in a sixth in that fiscal period and the five sixths remaining in equal parts in the following 5 fiscal periods. As of January 1, 2021, 100% of the adjustment may be deducted/taxed in the year in which the effect is determined.

Adjustment of acquisitions and investments made in fiscal years beginning on or after January 1, 2018

A cost adjustment mechanism is established for assets acquired or investments made in fiscal years beginning on or after January 1, 2018. The adjustment will be made based on the percentage variations of the IPIM.

Tax revaluation

It established the possibility of carrying out a tax revaluation, for a single time, of certain assets that are part of the assets as of December 31, 2017, in order to adjust their value.

The taxpayers that exercised the revaluation option waived to promote any judicial or administrative process for which the adjustment for tax inflation is claimed.

The Board of Directors decided to make use of this option.

On August 16, 2022, RG No. 5268/2022 was published through which the AFIP ordered an extraordinary advance of income tax. The extraordinary advance payment constitutes an additional payment on account to that provided for in the general advance payment regime that can be added to the latter. For fiscal year 2022, the Company paid the AFIP Ps. 3,367,653 for this concept.

Deferred Tax

The reconciliation between the charge computed for tax purposes and the income tax expense charged to the statement of comprehensive income in the years ended December 31, 2022, 2021 and 2020 is as follows:

	2022			2021			2020
Current income tax		(15,857,624	)		(26,694,111	)		(10,113,083	)
Deferred income tax		(1,203,529	)		1,883,262			(2,836,978	)
Total income tax		(17,061,153	)		(24,810,849	)		(12,950,061	)

The analysis of the net deferred tax assets and liabilities is as follows:

	2022			2021
Deferred tax assets:
Deferred tax assets to be recovered after more than 12 months		3,626,709			7,846,119
Deferred tax assets to be recovered after less than 12 months		1,412,828			1,247,816
Deferred tax liabilities:
Deferred tax liabilities taxable after more than 12 months		(25,574,208	)		(28,787,450	)
Deferred tax liabilities taxable after less than 12 months		(686,246	)		(323,873	)
Deferred tax liabilities, net		(21,220,917	)		(20,017,388	)

The components of the net deferred tax assets and liabilities as of December 31, 2022, 2021 and 2020 are the following:

Deferred tax assets	Other receivables			Account receivables discounted value			Provisions for legal claims and other provisions			Financial leases			Contract liabilities		Tax loss carryforward			Tax inflation adjustment			Financial assets at fair value through profit or loss		Total
As of December 31, 2020		39,744			1,891			656,071			2,140,878			1,880,469		2,776			49,211			-		4,771,040
Charge in results		(39,744	)		(115	)		351,911			(133,032	)		869,196		3,294,662			(19,983	)		-		4,322,895
As of December 31, 2021		-			1,776			1,007,982			2,007,846			2,749,665		3,297,438			29,228			-		9,093,935
Charge in results		-			(1,776	)		(366,049	)		(562,847	)		6,764		(3,297,438	)		(16,667	)		183,615		(4,054,398	)
As of December 31, 2022		-			-			641,933			1,444,999			2,756,429		-			12,561			183,615		5,039,537

Deferred tax liabilities	Other receivables			Loans			Property, Plant and Equipment			Cash and cash equivalents			Inventories			Financial assets at amortized cost			Tax inflation adjustment			Other liabilities			Total
As of December 31, 2020		-			(58,641	)		(15,369,172	)		(3,047	)		(98,569	)		(592,588	)		(10,549,673	)		-			(26,671,690	)
Charge in results		(5,226	)		(104,771	)		(6,035,973	)		(30,571	)		(28,274	)		592,588			3,424,894			(252,300	)		(2,439,633	)
As of December 31, 2021		(5,226	)		(163,412	)		(21,405,145	)		(33,618	)		(126,843	)		-			(7,124,779	)		(252,300	)		(29,111,323	)
Charge in results		(114,164	)		23,424			(1,417,423	)		(392,781	)		6,984			-			4,492,529			252,300			2,850,869
As of December 31, 2022		(119,390	)		(139,988	)		(22,822,568	)		(426,399	)		(119,859	)		-			(2,632,250	)		-			(26,260,454	)

As of December 31, 2021, the Company had a specific tax carryforward derived from negative exchange differences for the years 2021 and 2020 generated by financial instruments traded abroad for Ps. 3,662,207. The realization of such tax loss depended on the future generation of taxable financial gains taxed during the statute of limitations period. In order to determine its recoverability, the Company took into consideration the reversal of the deferred items, its tax planning and projections of future specific taxable income based on its best estimate. Based on these projections and because it was not possible to estimate as probable the generation of future specific financial gains to absorb such tax loss, no deferred tax asset of Ps. 364,769 was recognized as of December 31, 2021. During the year ended on December 31, 2022, the tax loss carryforward was totally recovered.

Income tax expense computed at the statutory tax rate on pre-tax income differs from the income tax expense for the years ended December 31, 2022, 2021 and 2020 as follows:

	2022			2021			2020
Pre tax income		49,378,955			65,583,161			22,612,275
Statutory income tax rate		35	%		35	%		30	%
Pre tax income at statutory income tax rate		(17,282,634	)		(22,954,106	)		(6,783,682	)
Tax effects due to:
- Restatement by inflation		2,968,108			11,276,529			6,159,982
- Tax loss variation		-			3,297,438			-
- Unrecognized tax loss carryforward		-			-			(5,988,032	)
- Adjustment affidavit previous year		(82,082	)		(131,655	)		(26,677	)
- Tax inflation adjustment		(2,717,831	)		(7,678,237	)		(8,159,343	)
- Variation of tax rate		-			(7,955,019	)		-
- Others		53,286			(665,799	)		1,847,691
Total income tax		(17,061,153	)		(24,810,849	)		(12,950,061	)

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PROVISIONS

12 Months Ended

Dec. 31, 2022

PROVISIONS [Abstract]

PROVISIONS

15. PROVISIONS

The total amount of the Provisions is included in current liabilities.

	For legal claims and others
Balances as of 12/31/2020		2,530,671
Inflation adjustment restatement		(1,023,648	)
Additions		1,036,496		(1)
Uses		(9,751	)
Decreases		(9,535	)	(3)
Balances as of 12/31/2021		2,524,233
Inflation adjustment restatement		(1,445,722	)
Additions		804,831		(2)
Uses		(20,248	)
Decreases		(29,000	)	(3)
Balances as of 12/31/2022		1,834,094

⁽¹⁾ Ps. 557,718 are included in “Other operating expenses” and Ps. 478,778 in “Financial expenses”.

⁽²⁾ Ps. 356,890 are included in “Other operating expenses” and Ps. 447,941 in “Financial expenses”.

⁽³⁾ The total are included in “Other operating expenses”.

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FINANCIAL RISK MANAGEMENT

12 Months Ended

Dec. 31, 2022

FINANCIAL RISK MANAGEMENT [Abstract]

FINANCIAL RISK MANAGEMENT

16. FINANCIAL RISK MANAGEMENT

16.1 Financial risk factors

The Company’s activities and the market in which it operates expose it to a series of financial risks: market risk (including foreign exchange risk, interest rate risk, and commodity price risk), credit risk and liquidity risk.

The Company’s risk management framework establishes that a risk map is determined that measures the potential impact of each of them on the financial situation and results of operations. Based on this, the Executive Officers are responsible for defining the policies, procedures, limits and measures aimed at mitigating the impact of said risks.

The sensitivity analyzes included below are based on the change in one of the factors while all others remain constant. In practice, this is unlikely to happen, and changes in several factors can be correlated, for example, in variations in the interest rate and variations in the foreign currency exchange rate.

Sensitivity analysis only provides limited vision, at one point in time. The actual impact on the Company’s financial instruments could vary significantly with respect to the impact shown in the sensitivity analysis.

16.1.1 Risk associated with exchange rates

Restrictions to the single free market for foreign exchange (“MULC”)

As mentioned in Note 1, the main global and Argentine economic variables have had a negative impact on financial markets affecting the cost of borrowing, hedging activities, liquidity and access to capital in general. In the local market, particularly, the shares of the main listed companies, sovereign bonds and the Argentine peso experienced a sharp drop in value.

Additionally, as from April 2020, through the issuance of Communication “A” 7001, subsequently amended by Communications “A” 7030, 7042, 7052, 7068 and 7138, the BCRA established measures that intensify the restrictions for access to the MULC, including measures related to the trading of stock market assets by companies.

In turn, on May 25, 2020 and June 19, 2020, the CNV issued General Resolutions No. 841 and 843, by means of which restrictions are established for the purchase and sale of negotiable securities in U.S. dollars, or the transfer of such securities to depositary companies abroad. Subsequently, by means of General Resolution No. 862, such agency provided certain flexibilities to the terms of permanence of such securities.

These measures aimed at restricting the MULC in order to contain the demand for dollars imply the request of prior authorization from the BCRA for certain transactions, including the following:

- Payment of dividends to non-residents;

- Payment of imports of certain goods abroad or cancellation of debts originated in the importation of such goods except for certain exceptions expressly provided for in the applicable regulations;

- The formation of foreign assets; and

- Payment of financial loans to non-residents.

In case of having requested access to the MULC, it must assume the commitment to enter and settle in the foreign exchange market, within five working days of its availability, those funds received abroad originated in the collection of loans granted to third parties, the collection of a time deposit or the sale of any type of asset, when the asset had been acquired, the deposit constituted or the loan granted after May 28, 2020.

Additionally, on September 15, 2020, the BCRA published Communications “A” 7105 and 7106 by which it is established, among other measures, that those who register financial debts with independent parties with principal maturities in foreign currency scheduled between October 15, 2020 and March 31, 2021, must submit to the BCRA a refinancing plan for the principal maturities based on the following criteria: (a) that the net amount for which the exchange market will be accessed in the original terms will not exceed 40% of the principal amount maturing in the period indicated above, and (b) that the remaining principal be, at least, refinanced with new external indebtedness with an average life of 2 years, provided that the new indebtedness is settled in the exchange market.

During 2022, although various regulations have been issued that, to a greater or lesser extent, provided for certain flexibility in access to the MULC, the BCRA continued to limit access to them in order to preserve its reserves and stabilize its exchange rate policy.

The aforementioned rule does not have immediate effect on the Company since the amortization of the principal of its marketable debentures occurs on May 2, 2025, which is not within the aforementioned term. On the other hand, as of the date of issuance of these consolidated financial statements, the Company paid all the interest installment corresponding to its financial debt on November 2, 2020.

Additionally, the exchange regime already determined as mandatory the entry and liquidation in local currency of the funds obtained as a result of the following operations and concepts, among others:

- Exports of goods and services;

- Collection of pre-financing, advances and post-financing of exports of goods;

- Exports of services;

- Disposal of foreign assets.

These foreign exchange restrictions, or those that may be enacted in the future, could affect the Company’s ability to access the official foreign exchange market to acquire the foreign currency necessary to meet its financial obligations. Assets and liabilities denominated in foreign currency as of December 31, 2021 have been valued considering the current exchange rates in the MULC.

Exchange rate risk management

In view of the main impacts of the aforementioned situation and those detailed in Note 1 to these Consolidated Financial Statements, the Company has implemented a series of measures to mitigate their impact. In this sense, the Company’s Management permanently monitors the evolution of the situations that affect its business, in order to determine the possible actions to be taken and identify the eventual impacts on its equity and financial situation. The Company considers that its current financial position will allow it to comply, in the short term, with its foreign currency commitments. The Company’s financial statements should be read in light of these circumstances.

The Company is primarily exposed to the fluctuation of the exchange rate of the U.S. dollar against the Argentine Peso due to the fact that almost its entire financial indebtedness is denominated in U.S. dollars. The exposure to other currencies is not significant.

As regards to the revenue derived from the Natural Gas Transportation segment, the tariffs charged by the Company are currently denominated in Argentine pesos. On the other hand, revenues in US dollars derived from the Liquids Production and Commercialization segment accounted for approximately 87% of the segment’s total revenues for the years ended December 31, 2022, 2021 and 2020. Total operating cost denominated in Argentine Pesos accounted for 83%, 81% and 80% for the years ended December 31, 2022, 2021 and 2020, respectively.

As of December 31, 2022, 2021 and 2020, 35%, 37% and 50% of total revenues are denominated in Argentine pesos, respectively.

tgs’ financial risk management policies are defined with the objective of mitigating the impact of exchange rate fluctuations on the Company’s foreign currency position. To this end, alternative investment evaluations are regularly carried out to diversify tgs’ investment portfolio among instruments denominated in U.S. dollars or, although denominated in Argentine pesos, to obtain positive returns in real terms.

Additionally, if deemed appropriate, the Company enters into derivative financial instruments that allow hedging the fluctuation of the U.S. dollar on the positions in such currency in the long term. During fiscals years 2020 and 2019, the Company did not contract derivative financial instruments to hedge this risk.

However, the Company, in order to mitigate the impact on the future variation of the exchange rate, has placed funds in assets denominated in U.S. dollars. As of December 31, 2022, 89% of the Company’s fund placements are denominated in U.S. dollars.

For further information regarding the Company’s foreign currency position see “Note 18. Foreign currency assets and liabilities”.

Management of the Company estimates that, based on the net liability position as of December 31, 2022 and 2021, a 10% appreciation in the exchange rate of the U.S. dollar against the Argentine peso, with all other economic-financial variables stable, could have resulted in a pre-tax loss of Ps. 1,975,626 and Ps. 3,962,154, respectively. A 10% depreciation of the U.S. dollar against the Argentine peso would have an equal and opposite effect on the Statement of Comprehensive Income. This sensitivity analysis is theoretical as the actual impacts could differ significantly and vary over time.

In order to mitigate the exchange rate risk, during fiscal year 2022, tgs entered into both forward purchase operations of US dollars, as well as investments in mutual funds linked to the US dollar in order to hedge exposure to the risk associated with the exchange rate that derives from its financial debt.

16.1.2 Interest rate risk

Interest rate risk management seeks to reduce financial costs and limit the Company’s exposure to increases in interest rates. tgs’ exposure to risks associated with interest rate variations is limited given that all of its financial debt is subject to fixed interest rates. Information regarding the Company’s financing is disclosed in Note 13.

In addition, the main objective of the Company’s financial investment activities is to obtain the highest return by investing in low-risk and highly liquid instruments. The Company maintains a portfolio of cash equivalents and short-term investments comprised of investments in mutual funds and deposits in interest-bearing bank accounts, public and private securities. The risk of these instruments is low since they are mostly short-term and highly liquid in recognized financial institutions.

As a consequence of the application of IAS 29, maintaining monetary assets generates loss of purchasing power, provided that such items are not subject to an adjustment mechanism that compensates to some extent the loss of purchasing power. This loss of purchasing power is included in the result of the period under gain on the net monetary position. On the contrary, maintaining monetary liabilities generates a gain in purchasing power, which are also included in such line item.

The Company’s risk management policies are defined with the objective of reducing the impact of the loss of purchasing power. During the 2022, 2021 and 2020 fiscal years the Company has maintained a liability monetary position. As a consequence, tgs has recorded a net gain from exposure to inflation in the monetary items.

The following table shows a breakdown of the Company’s fixed-rate and floating-rate financial assets and liabilities as of December 31, 2022 and 2021:

	Financial assets				Financial liabilities (1)
	2022		2021		2022		2021
Fix interest rate		39,323,688		43,932,998		86,048,279		96,533,363
Variable interest rate		2,665,814		34,048,991		-		-
Total		41,989,502		77,981,989		86,048,279		96,533,363

⁽¹⁾ Includes 2018 Notes. For further information see Note 13 to the Consolidated Financial Statements.

In view of the nature of the Company’s financial assets which bear variable interest, an immediate 100 basis points decrease in the interest rate would not have a significant impact on the total value of the financial assets.

16.1.3 Commodity price risk

Commercial operations performed by the Company in its Liquids Production and Marketing segment are affected by a number of factors beyond its control, including changes in the international prices of the products sold, and government regulations on prices, taxes and other charges, among others.

The sales prices of exported propane, butane and natural gasoline are determined according to international reference prices (Mont Belvieu for propane and butane and NWE ARA for natural gasoline). Additionally, most of the total sales of propane and butane that are made in the domestic market are made at prices set by the Ministry of Energy for the different market segments.

These prices have historically fluctuated in response to macroeconomic conditions and changes in supply and demand, which could affect tgs’ profitability. Especially during the first half of 2020, and due to the effect of COVID and the international oil market situation, the price of Liquids was negatively affected with year-on-year declines during that period in the order of 30%. However, as of the last quarter of 2020 and after the end of the year, international prices recovered sharply.

Based on volume of sales for the years ended December 31, 2022, 2021 and 2020, tgs estimated that, other factors being constant, a decrease of US$ 50 per ton in the international price of LPG and natural gasoline, respectively, would have decrease the Company’s net comprehensive income in its Liquids Production and Commercialization segment in Ps. 3,207,213, Ps. 4,378,871 and Ps. 5,935,956, respectively. On the other hand, an increase of US$ 50 per ton in the international price would have had the opposite effect.

16.1.4 Credit risk

The Company’s exposures to credit risk takes the form of a loss that would be recognized if counterparties failed to, or were unable to, meet their payment obligations. These risks may arise in certain agreements in relation to amounts owed for physical product sales, the use of derivative instruments, and the investment of surplus cash balances. This risk mainly results from economic and financial factors or from a possible default of counterparty.

The Company is subject to credit risk arising from outstanding receivables, cash and cash equivalents and deposits with banks and financial institutions, and from the use of derivative financial instruments. The Company’s policy is to manage credit exposure to trading counterparties within defined trading limits.

To measure the expected credit loss, receivables from sales have been grouped according to their characteristics in terms of credit risk and the time that has elapsed since maturity.

On this basis, the provision for losses for the year ended December 31, 2022 for trade receivables was determined as follows:

Ratio	Non-due			90 days			120 days			180 days			+240 days
Natural Gas Transportation segment		0	%		0.50	%		5	%		10	%		100	%
Other segments		0	%		0.25	%		2	%		5	%		100	%

Trade and other receivables

If any of the Company’s customers are independently rated, these ratings are used. Otherwise, if there is no independent rating, the Company assesses the credit quality of the customer taking into account its financial position, past experience and other factors. The Company may seek cash collateral, letter of credit or parent company guarantees, as considered appropriate.

As of December 31, 2022 and 2021, current and non-current sales receivables, net of allowance for doubtful accounts, amounted to:

	2022			2021
Current trade receivables		17,071,816			20,951,996
Allowances for doubful accounts (1)		(132,521	)		(258,142	)
Total		16,939,295			20,693,854

⁽¹⁾
Said amount represents the best estimate made by tgs according to what is stated in Note 4.b).

       Likewise, as of December 31, 2022 and 2021, the Company has credits for subsidies with the Argentine government for Ps. 3,768,159 and Ps. 2,427,450, respectively.

In the ordinary course of business, the Company provides natural gas transportation services mainly to natural gas distribution companies, CAMMESA and Pampa Energía. The amounts of net sales made to the principal customers to which Natural Gas Transportation services were provided in the years ended December 31,2022, 2021 and 2020 and the sales receivable balances (net of allowances) as of December 31, 2022 and 2021 are set forth below:

	2022				2021				2020
	Revenues		Trade receivables		Revenues		Trade receivables		Revenues
MetroGas		10,355,756		768,193		11,821,815		2,809,625		17,330,099
Camuzzi Gas Pampeana S.A.		7,668,510		567,671		8,708,964		681,780		12,813,975
Naturgy Argentina		6,286,027		483,552		7,051,418		586,216		10,358,472
CAMMESA		3,795,168		1,380,126		5,400,240		1,194,018		6,887,604
Pampa Energía		1,471,413		111,450		1,666,555		637,807		2,473,548
Camuzzi Gas del Sur S.A.		1,816,770		118,208		2,012,977		294,958		3,066,612

The amounts of Liquids Production and Marketing net sales made to major customers during the years ended December 31, 2022, 2021 and 2020 and sales receivable balances (net of allowances) as of December 31, 2022 and 2021 are set forth below:

	2022				2021				2020
	Revenues		Trade receivables		Revenues		Trade receivables		Revenues
PBB Polisur		25,589,826		3,569,289		26,657,675		2,778,544		27,355,042
Petredec		-		-		-		-		2,032,373
Geogas Trading S.A.		3,668,557		-		7,402,250		5,235,421		845,467
Italgas S.A.		-		-		295,028		-		1,165,237
YPF		2,598,667		160,887		3,700,237		66,832		2,862,061
Petrobras Global Trading BV		280,416		-		10,953,530		-		13,263,199
Trafigura Beheer		15,968,772		898,027		13,490,509		1,347,151		-
Pampa Energía		3,583,230		281,774		4,996,215		659,046		-

The amounts of Other Services net sales made to major customers during the years ended December 31, 2022, 2021 and 2020 and sales receivable balances (net of allowances) as of December 31, 2022 and 2021 are set forth below:

	2022				2021				2020
	Revenues		Trade receivables		Revenues		Trade receivables		Revenues
Tecpetrol		2,270,548		417,806		875,955		87,291		176,811
Exxonmobil Exploration		1,633,267		242,524		1,854,769		243,569		1,682,932
YPF		4,278,334		845,134		4,530,193		893,039		3,954,508
Vista Oil		235,425		121,741		-		26,881		-
Pluspetrol		2,638,534		275,192		2,352,809		535,042		1,730,764
Pampa Energía		3,972,826		906,281		2,365,465		523,735		1,792,010

Cash and financial placements

The credit risk on cash and cash equivalents and other financial placements is limited since tgs has short-term fund placement policies whose main objective is to obtain an adequate return based on market characteristics and minimizing risk exposure. These placements are diversified in different financial institutions with adequate credit ratings in order to limit exposure to a few financial institutions. The Company’s maximum exposure to credit risk will be given by the carrying value of assets included in cash and cash equivalents and other financial assets at amortised cost.

During the years 2022, 2021 and 2020 the Company has carried out transactions with financial instruments traded abroad, mainly national and provincial government bonds, which resulted in exchange losses of Ps. 1,613,742, Ps. 3,694,962 and Ps. 23,456,438, respectively, which are recorded as “Other financial results - Result from valuation at fair value of financial assets through profit or loss” in the Statement of comprehensive income for the year ended December 31, 2022, 2021 and 2020.

Below is a detail of the maturities of the financial assets included in (i) cash and cash equivalents, (ii) other financial assets, (iii) trade receivables and  (iv) other receivables as of December 31, 2022 and 2021:

December 31, 2022
	Cash and cash equivalents		Other financial assets		Credits (1) (2)
Without specified maturity		2,988,946		39,289,630		40,389
With specified maturity
Overdue
Until 12-31-2021		-		-		173,477
From 01-01-22 to 03-31-22		-		-		8,167
From 04-01-22 to 06-30-22		-		-		26,427
From 07-01-22 to 09-30-22		-		-		22,530
From 10-01-22 to 12-31-22		-		-		1,449,545
Total overdue		-		-		1,680,146
Non-due
From 01-01-23 to 03-31-23		-		192		19,536,293
From 04-01-23 to 06-30-23		-		192		113,994
From 07-01-23 to 09-30-23		-		1,054		57,932
From 10-01-23 to 12-31-23		-		-		3,753
During 2024		-		40,162,283		14,026
During 2025		-		-		-
During 2026		-		-		-
From 2027 onwards		-		-		-
Total non-due		-		40,163,721		19,725,998
Total with specified maturity		-		40,163,721		21,406,144
Total		2,988,946		79,453,351		21,446,533

⁽¹⁾ The total amount of the receivables without specified maturity is recorded in Non-current assets.

⁽²⁾ Includes financial assets recorded in trade receivables and other receivables, excluding allowance for doubtful accounts.

December 31, 2021
	Cash and cash equivalents		Other financial assets		Credits (1) (2)
Without specified maturity		8,627,004		24,456,434		73,421
With specified maturity
Overdue
Until 12-31-2020		-		-		264,751
From 01-01-21 to 03-31-21		-		-		-
From 04-01-21 to 06-30-21		-		-		-
From 07-01-21 to 09-30-21		-		-		81,875
From 10-01-21 to 12-31-21		-		-		3,376,015
Total overdue		-		-		3,722,641
Non-due
From 01-01-22 to 03-31-22		-		1,350		19,607,691
From 04-01-22 to 06-30-22		-		1,143		587,968
From 07-01-22 to 09-30-22		-		732		112,848
From 10-01-22 to 12-31-22		-		497		939
During 2023		-		45,108,956		14,377
During 2024		-		-		-
During 2025		-		-		-
From 2026 onwards		-		-		-
Total non-due		-		45,112,678		20,323,823
Total with specified maturity		-		45,112,678		24,046,464
Total		8,627,004		69,569,112		24,119,885

⁽¹⁾ The total amount of the receivables without specified maturity is recorded in Non-current assets.

⁽²⁾ Includes financial assets recorded in trade receivables and other receivables, excluding allowance for doubtful accounts.

16.1.5 Liquidity risk

This risk involves the difficulties that tgs may have in meeting its commercial and financial obligations. To this end, the expected cash flow is regularly monitored.

tgs has policies for borrowing funds whose main objective is to cover financing needs at the lowest cost according to market conditions. One of the Company’s main objectives is to have financial solvency. Given the current conditions of the financial market, the Company believes that the availability of resources and the positive cash flow from operations are sufficient to meet its current obligations, despite having credit lines for borrowing funds.

Additionally, a methodology is used for the analysis and assignment of credit limits to the different financial entities in order to minimize the associated liquidity risk. In line with this, the Company invests its liquid funds in financial entities with an adequate credit rating.

Below is a detail of the maturities of the Company’s financial liabilities corresponding to: commercial debts, remunerations, other debts and financial debts as of December 31, 2022 and 2021. The amounts presented in the tables represent contractual undiscounted cash flows and, therefore, do not correspond to the amounts presented in the statement of financial position. These estimates are made on the basis of information available at the end of each year and may not reflect actual amounts in the future. Therefore, the amounts shown are provided for illustrative purposes only:

December 31, 2022
	Loans		Other financial liabilities		Leases liabilities
Without specified maturity		-		-		-
With specified maturity
Overdue
Until 12-31-2021		-		230,673		-
From 01-01-22 to 03-31-22		-		311		-
From 04-01-22 to 06-30-22		-		311		-
From 07-01-22 to 09-30-22		-		311		-
From 10-01-22 to 12-31-22		-		311		133,549
Total overdue		-		231,917		133,549
Non-due
From 01-01-23 to 03-31-23		-		12,547,599		331,289
From 04-01-23 to 06-30-23		3,316,733		78,747		331,289
From 07-01-23 to 09-30-23		1,541,798		-		331,289
From 10-01-23 to 12-31-23		2,989,575		-		331,289
During 2024		5,979,150		-		1,325,334
During 2025		91,569,575		-		1,325,334
During 2026		-		-		791,728
From 2027 onwards		-		-		-
Total non-due		105,396,831		12,626,346		4,767,552
Total with specified maturity		105,396,831		12,858,263		4,901,101
Total		105,396,831		12,858,263		4,901,101

December 31, 2021
	Loans		Other financial liabilities		Financial leases
Without specified maturity		-		-		-
With specified maturity
Overdue
Until 12-31-2020		-		576,851		-
From 01-01-21 to 03-31-21		-		606		-
From 04-01-21 to 06-30-21		-		606		-
From 07-01-21 to 09-30-21		-		606		-
From 10-01-21 to 12-31-21		-		606		150,834
Total overdue		-		579,275		150,834
Non-due
From 01-01-22 to 03-31-22		82,329		14,066,957		374,170
From 04-01-22 to 06-30-22		3,376,545		82,164		374,170
From 07-01-22 to 09-30-22		-		-		374,170
From 10-01-22 to 12-31-22		3,376,545		-		374,170
During 2023		6,753,090		-		1,496,884
During 2024		6,753,090		-		1,496,884
During 2025		103,422,323		-		1,496,884
From 2026 onwards		-		-		894,210
Total non-due		123,763,922		14,149,121		6,881,542
Total with specified maturity		123,763,922		14,728,396		7,032,376
Total		123,763,922		14,728,396		7,032,376

16.1.6 Capital management risk.

The Company’s objectives in managing capital are to safeguard the Company’s ability to continue as a going concern, to achieve an optimal cost of capital structure and to support the investment process in order to provide returns to shareholders and benefits to other stakeholders.

tgs seeks to maintain a level of cash generation from its operating activities that will enable it to meet all of its commitments.

The Company monitors capital on the basis of the leverage ratio. This ratio is calculated as total financial debt (including “current financial debt” and “non-current financial debt” as shown in the Statement of Financial Position) divided by total capital. Total capital is calculated as “Shareholders’ Equity”, as shown in the Statement of Changes in Shareholders’ Equity, plus total financial debt.

During the years ended December 31, 2022 and 2021, the gearing ratio was as follows:

	2022		2021
Total debt (Note 13)		94,614,065		102,421,012
Total equity		267,224,289		234,906,487
Total capital		361,838,354		337,327,499
Gearing Ratio		0.26		0.30

    16.2 Financial instruments by category and level of hierarchy

16.2.1 Categorization of financial instruments

The accounting policies for the categorization of financial instruments were explained in Note 4.e. In accordance with IFRS 7, IAS 32 and IFRS 9, non-financial assets and liabilities, such as contract and supplier liabilities, tax and social charges, income tax and deferred income tax are not included.

The categorization of financial assets and liabilities as of December 31, 2022 and 2021 is included below:

	December 31, 2022
	Financial assets at fair value		Financial assets at amortized cost		Total
CURRENT ASSETS
Trade receivables		-		16,939,295		16,939,295
Other receivables		-		4,359,818		4,359,818
Financial assets at amortized cost		-		1,438		1,438
Financial assets at fair value through profit or loss		39,289,630		-		39,289,630
Cash and cash equivalents		2,665,814		323,132		2,988,946
Total current assets		41,955,444		21,623,683		63,579,127
NON-CURRENT ASSETS
Other receivables		-		14,899		14,899
Other financial assets at amortized cost		-		40,162,283		40,162,283
Total non-current assets		-		40,177,182		40,177,182
Total assets		41,955,444		61,800,865		103,756,309

	Financial liabilities at fair value		Other financial liabilities		Total
CURRENT LIABILITIES
Trade payables		-		10,524,936		10,524,936
Loans		-		3,919,929		3,919,929
Payroll and social security taxes payables		-		2,153,524		2,153,524
Other payables		-		286,555		286,555
Total current liabilities		-		16,884,944		16,884,944
NON-CURRENT LIABILITIES
Loans		-		90,694,136		90,694,136
Total non-current liabilities		-		90,694,136		90,694,136
Total liabilities		-		107,579,080		107,579,080

	2021
	Financial assets at fair value		Financial assets at amortirzed cost		Total
CURRENT ASSETS
Trade receivables		-		20,693,854		20,693,854
Other receivables		-		3,151,559		3,151,559
Financial assets at amortized cost		-		3,721		3,721
Financial assets at fair value through profit or loss		25,844,992		-		25,844,992
Cash and cash equivalents		8,197,972		429,032		8,627,004
Total current assets		34,042,964		24,278,166		58,321,130
NON-CURRENT ASSETS
Other receivables		-		16,330		16,330
Financial assets at amortized cost		-		43,720,399		43,720,399
Total non-current assets		-		43,736,729		43,736,729
Total assets		34,042,964		68,014,895		102,057,859

	Financial liabilities at fair value		Other financial liabilities		Total
CURRENT LIABILITIES
Trade payables		-		11,820,683		11,820,683
Loans		-		2,299,738		2,299,738
Derivative financial results		82,329		-		82,329
Payroll and social security taxes payables		-		2,279,022		2,279,022
Other payables		-		619,970		619,970
Total current liabilities		82,329		17,019,413		17,101,742
NON-CURRENT LIABILITIES
Loans		-		100,121,274		100,121,274
Total non-current liabilities		-		100,121,274		100,121,274
Total liabilities		82,329		117,140,687		117,223,016

16.2.2 Fair value measurement hierarchy and estimates

According to IFRS 13, the fair value hierarchy introduces three levels of inputs based on the lowest level of input significant to the overall fair value. These levels are:

Level 1: includes financial assets and liabilities whose fair values are estimated using quoted prices (unadjusted) in active markets for identical assets and liabilities. The instruments included in this level primarily include balances in mutual funds and public or private bonds listed on the Bolsas y Mercados Argentinos S.A. (“BYMA”). Within this level, the Company includes those derivate financial instruments for which it was able to find an active market.

Level 2: includes financial assets and liabilities whose fair value is estimated using different assumptions quoted prices included within Level 1 that are observable for the asset or liability, either directly (i.e. as prices) or indirectly (for example, derived from prices).

Level 3: includes financial instruments for which the assumptions used in estimating fair value are not based on observable market information.

During 2022 and 2021, there were no transfers between the different hierarchies used to determine the fair value of the Company’s financial instruments or reclassifications between categories of financial instruments.

The table below shows different assets at their fair value classified by hierarchy as of December 31, 2022 and 2021:

	As of December 31, 2022
	Level 1		Level 2		Level 3		Total
Financial assets at fair value
Cash and cash equivalents		2,665,814		-		-		2,665,814
Financial assets at fair value through profit or loss		39,289,630		-		-		39,289,630
Total		41,955,444		-		-		41,955,444

	As of December 31, 2021
	Level 1		Level 2		Level 3		Total
Financial assets at fair value
Cash and cash equivalents		8,197,972		-		-		8,197,972
Financial assets at fair value through profit or loss		25,844,992		-		-		25,844,992
Total		34,042,964		-		-		34,042,964

	Level 1		Level 2		Level 3		Total
Financial liabilities at fair value
Derivative financial instruments		82,329		-		-		82,329
Total		82,329		-		-		82,329

The fair value amount of the financial assets is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date.

As of December 31, 2022, the carrying amount of certain financial instruments used by the Company, in cash, cash equivalents, other investments, accounts receivable and payable and short-term obligations is representative of fair value due to the short-term nature of these instruments. Also, the carrying value of non-current financial assets measured at amortised cost consists of time deposits made with financial institutions at current market rates.

The estimated fair value of Non-current loans is estimated based on quoted market prices (level 1). The following table reflects the carrying amount and estimated fair value of the 2018 Notes at December 31, 2022, based on their quoted market price:

	As of December 31, 2022
	Carrying amount		Fair value
2018 Notes		84,229,875		77,460,798

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REGULATORY FRAMEWORK

12 Months Ended

Dec. 31, 2022

REGULATORY FRAMEWORK [Abstract]

REGULATORY FRAMEWORK

17. REGULATORY FRAMEWORK

a) General framework of the natural gas transportation segment:

General aspects

Regarding tgs’ Natural Gas Transportation business, it is regulated by Law No. 24,076 (“the Natural Gas Act”), its regulatory Decree No. 1,738/92 and the Regulatory framework for the transportation and distribution of natural gas in Argentina. The Natural Gas Act created ENARGAS, which is entitled, among other things, to set the basis for the calculation, monitoring, approval of tariffs and the power to verify compliance with the Natural Gas Law and its regulations. On January 28, 2016, Resolution No. 7 of the MINEM of Argentina repealed the Resolution 2000/2005 of the former Ministry of MPFIPyS which provided that all tariff increases should have the prior intervention of the Undersecretary of Coordination and Management Control.

tgs’ License has been granted for an original period of 35 years beginning on December 28, 1992. However, the Natural Gas Act provides that tgs may apply to ENARGAS for a renewal of its license for an additional period of ten years. ENARGAS should evaluate at that time the performance of tgs and raise a recommendation to the Executive Branch. At the end of the period of validity of the license, 35 or 45, as appropriate, the Natural Gas Act requires a call for a new tender for the granting of a new license, in which tgs, provided the Company fulfilled substantially with the obligations resulting from the license, would have the option of matching the best offer that the Government received in this bidding process.

Tariff situation

Prior the enactment of the Public Emergency Law, and according to the Regulatory Framework, transportation tariffs were to be calculated in US dollars and converted into Argentine pesos at the time the customer was billed using the exchange rate prevailing at the date of the billing. The basic natural gas transportation tariffs charged by tgs had been established at the time of the privatization of GdE and were to be adjusted, subject to prior authorization, in the following cases: (i) semiannually to reflect changes in the US producer price index (“PPI”) and (ii) every five years according to efficiency and investment factors determined by ENARGAS. The “efficiency factor” was a reduction to the base tariff resulting from future efficiency programs while the “investment factor” increased the tariffs to compensate the licensees for future investments which were not repaid through tariffs. Also, subject to ENARGAS approval, tariffs were to be adjusted to reflect non-recurrent circumstances or tax changes, other than income tax.

The terms and conditions as described in the precedent paragraph in connection with tariff adjustments contemplated within the Regulatory Framework are no longer effective since the enactment of the Public Emergency Law in early 2002, which, among other provisions, eliminated tariff increases based on US dollar exchange rate fluctuations, foreign price indexes or any other indexing procedure and established a conversion rate of one peso to one US dollar for tariffs. The Public Emergency Law also granted the Executive Branch power to renegotiate contracts entered into with private utility companies, pursuant to the framework included in such law as long as it is in force, which expired on December 31, 2017, after several extensions.

Between July 2003 and March 2018, the Company received a series of temporary tariff increases under the framework of the Integral Tariff Review (“RTI” for its acronym in Spanish) process initiated after the Public Emergency Law was passed.

On March 27, 2018, the Executive Branch of the Argentine Government issued the Decree No. 250/2018 (the “Decree 250”) ratifying the 2017 Integral Agreement. This decree represents the conclusion of the RTI process and the completion of the 2017 Transitional Agreement, and thus, the final renegotiation of the license after seventeen years of negotiations.

The 2017 Integral Agreement sets the guidelines for the provision of the natural gas transportation service until the end of the License. Among these guidelines:

• The RTI Process, which will culminate in the signing of the integral agreement, was approved. As a result of this RTI, a new tariff schedule was also approved. This new tariff schedule applicable to the Company determined a total tariff increase of 214.2% and 37%, in the event that it had been granted in a single installment as of April 1, 2017, on the tariff of the natural gas transportation service and the CAU, respectively.

• The Five-Year Investment Plan was approved. Resolution 4362 obliged tgs for the execution of the Five-Year Plan, which requires a high level of essential investments for the operation and maintenance of the pipeline system, to provide quality, safe and reliable service. The Five-Year Plan shall be for the period from April 1, 2017 to March 31, 2022 and will amount to Ps. 6,786,543, expressed in December 31, 2016 currency terms.

• A non-automatic six-month adjustment mechanism for the natural gas transportation tariff and the investment commitments were approved. This adjustment must be approved by ENARGAS and for its calculation, the evolution of the WPI published by INDEC will be considered.

• tgs and its shareholders must withdraw any claim against the Government related to the natural gas transportation business, including the arbitration proceedings before the ICSID. The Company desisted from it on June 26, 2018.

As it is mentioned above the tariff increase was granted in 3 installments according to the following resolutions:

• Effective as of April 1, 2017, 64.2% of the tariff for the natural gas transport service, the CAU not being adjusted, in accordance with the provisions of Resolution No. 4362/2017 (“Resolution 4362”).

• Effective as of December 1, 2017, after the issuance of Resolution 120, 81.1% on the tariff for the natural gas transport service and 29.7% on the CAU, which includes the first adjustment by WPI.

• Effective as of April 1, 2018, an increase of 50% over the tariff for the natural gas transport service and the CAU within the framework of the provisions of Resolution No. 310/2018 issued by ENARGAS.

Semiannual tariff increase

This increase is granted within the framework of the semi-annual tariff adjustment of the natural gas transportation service in accordance with the provisions of the RTI process.

In the public hearing held on September 4, 2018, in which the Company requested, based on the variation of the WPI recorded for the period February - August 2018, a tariff increase of approximately 30%. Considering the hearing, on September 27, 2018, ENARGAS issued Resolution No. 265/2018 which determined a 19.7% tariff increase effective as of October 1, 2018.

This increase was determined by ENARGAS based on the simple average of the WPI, the Construction Cost Index for the period February and August 2018 and the Salary Variation Index between December 2017 and June 2018.

It is noteworthy that ENARGAS supported the determination of the aforementioned tariff increase in the provisions of Resolution 4362, which, among other issues, provided that under certain circumstances and macroeconomic conditions, such as the significant devaluation occurred after April 2018, ENARGAS may use other indexes than the WPI to determine the tariff increase. tgs notified ENARGAS its disagreement with respect to the methodology for calculating the semi-annual adjustment.

On March 29, 2019, ENARGAS issued Resolution No. 192/2019 (“Resolution 192”) that approved, effective as of April 1, 2019, a 26% increase in the tariff chart applicable to the public service of natural gas transportation by tgs in force as of March 31, 2019.

In accordance with current regulations, ENARGAS has considered the evolution of the wholesale price index update index (“WPI”) between the months of August 2018 and February 2019, in order to define the semi-annual adjustments applicable to tgs tariffs.

Regarding the semi-annual tariff adjustment that was to be enforced as from October 1, 2019, on September 3, 2019, the SE issued Resolution No. 521/2019 (“Resolution 521”) postponing it to February 1, 2020.

The deferral also meant that the Company reviewed and fit, in equal proportion to the revenue that is no longer received, the execution of the Five-Year Investment Plan. As of the date of the issuance of these Consolidated Financial Statements, tgs made the proposal to ENARGAS and the corresponding approval resolution have not yet been issued.

Nevertheless, the Solidarity Law establishes that natural gas transportation and distribution tariffs will remain unadjusted for a period of 180 as days from December 23, 2019. In this sense, the Executive Branch is authorized to renegotiate them, either within the framework of the current RTI or through an extraordinary review in accordance with the provisions of the Natural Gas Law.

On June 9, 2020, through Resolution No. 80/2020, ENARGAS created the Coordination and Centralization Commission - Law No. 27,541 and Decree No. 278/20, which will have the purpose of coordinating the comprehensive tariff review process set forth in Article 5 of the Solidarity Law.

On June 19, 2020, the PEN issued Decree No. 543/2020 by which the natural gas transportation and distribution tariffs were extended without adjustments for an additional term of 180 calendar days, that is, until December 16, 2020.

By provision of the Necessity and Urgency Decree No. 1,020/2020 (“Decree 1,020”), ENARGAS, commissioned by the PEN, began the renegotiation of the RTI concluded in 2018, which may not exceed 2 years. Until then, the current renegotiation agreements are suspended. Said renegotiation remains in the power of ENARGAS ad referendum of the PEN.

In addition, Decree 1,020 extends the tariff freeze for an additional period of 90 calendar days or until transitory tariffs are approved. It should be noted that all agreements, whether transitory or general, entered into with the National Government must not only be subject to the public hearing procedures provided by the regulations in force, but also to the authorization of the different governmental agencies.

Additionally, the Solidarity Law provides for the administrative intervention of ENARGAS, recently extended through Decree 1,020.

On March 16, 2021, the public hearing convened by ENARGAS was held for the purposes of considering the Transitional Tariff Regime (“RTT”) in accordance with the provisions of Decree 1,020. In this regard, tgs, without renouncing the full percentage of tariff recomposition that corresponds to it, alternatively presented at this hearing a proposal for a tariff increase calculated by 58.6%, as of April 1, 2021. It was calculated based on the financial needs to meet the operating and financial costs, capital investments and taxes, which were calculated considering the evolution of the inflation rate for a period of 12 months from its inception. Such requested increase contemplated only the necessary funds to meet the obligations as a licensee.

Additionally, in such public hearing, tgs denied and dismissed the arguments raised in it that considered that the current natural gas transportation tariff is not fair and reasonable given the alleged existence of serious defects in the administrative acts derived from the processing of the last Regime Comprehensive Tariff (“RTI”) made for tgs.

On April 28, 2021, ENARGAS sent to tgs, a Transitory Agreement Project 2021 within the framework of the provisions of Decree 1,020. Said project provided:

• The non-granting of a temporary tariff increase, keeping the tariff schedules approved by ENARGAS in April 2019 unchanged.

• It established that from May 2021 and until the Definitive Renegotiation Agreement is in force, ENARGAS will proceed to re-calculate the transportation tariffs at that time in force with effect from April 1, 2022.

• It did not establish a mandatory investment plan.

• The prohibition of: (i) distribution of dividends, (ii) an early cancellation of financial and commercial debts contracted with shareholders, and (iii) the acquisition of other companies or granting loans.

On April 30, 2021, through a note sent to that body, tgs stated that, given the context in which it develops its activities and the proposed terms and conditions, it was not feasible for the Company to sign the 2021 Temporary Agreement Project.

Subsequently, on June 2, 2021, ENARGAS issued Resolution No. 149/2021 (the “Resolution 149”) approving an RTT for tgs effective as of that date. The RTT (i) does not grant a temporary tariff increase in favor of the Company, but the current tariff schedules in force since April 1, 2019 remain unchanged; (ii) provides that from the entry into force of the Transitional Regime -and until the Definitive Renegotiation Agreement is in force- the possibility is contemplated that ENARGAS adjusts the rates of tgs as of April 1, 2022 ; (iii) does not establish a mandatory investment plan for tgs and (iv) establishes the prohibition to distribute dividends and prepay financial and commercial debts contracted with shareholders, acquire other companies or grant loans.

In July 2021, tgs filed appeals for reconsideration with the PEN, the Ministry of Economy of the Nation and ENARGAS with an appeal or hierarchical subsidy in accordance with the respective powers of each of these bodies in the dictation of the entire regulatory plexus associated with Resolution 149, (Decree 1020/20, Decree 353/21, and Joint Resolution No. 1/2021), requesting that the RTT be declared null and void and the RTI be restored. We recall that the RTT began with Decree 1020/20, which set the guidelines to carry out the renegotiation of the RTI, later issuing Joint Resolution 1/21, which sets the RTT, and Decree 353/21, which approved Joint Resolution 1 /21, and culminates with Resolution 149, which approved the new tariff charts.

The challenges are based on: i) the illegality of Decree 1020 because it does not follow the lines of the delegation provided for in Law 27,541, and as a Decree of Necessity and Urgency it does not comply with the requirements of the Constitution for the issuance of this regulation; ii) the extension of the emergency beyond that provided by Congress; iii) the failure to carry out the tariff renegotiation as provided for in Law 24. 076; iv) the disregard of the principle of fair and reasonable tariffs, and the acquired rights of tgs in the License, the Contractual Adjustment Agreement and the RTI; and v) the suspension of the RTI for reasons of public interest, which merits the recognition of the compensations, provided by both the Administrative Procedures Law and the Basic Rules of the License.

The restrictions imposed on the management and management of the Company, which have no legal justification, are also questioned, given that the emergency declared by Law No. 27,541 only empowered the National Executive Power to renegotiate the RTI and not the License.

The challenges and the request for reinstatement of the RTI have been made without prejudice to the right of tgs to pay the compensation that corresponds to it for not having complied with the RTI since April 2019.

On November 15, 2021, the Company filed a Prior Administrative Claim before ENARGAS and the Ministry of Economy. The purpose of said presentation is to request the compensation that corresponds to tgs for the lack of application of the semi-annual adjustment methodology established in the RTI approved by Resolution 362 between October 1, 2019 and June 1, 2021.

In addition, payment of compensation for the damages suffered by tgs due to the freezing caused by the failure to apply the six-monthly adjustment methodology established in the RTI in the aforementioned period is requested.

On January 19, 2022, a new public hearing was held, within the framework of ENARGAS Resolution No. 518/2021, whose purpose was to deal with a transitory tariff adjustment within the framework of Decree 1020/2020. In such hearing, with the purpose of reaching a definitive agreement on the renegotiation and recomposing the license economic-financial equation, tgs requested a transitory tariff adjustment applied in two stages for the year 2022 for a total of 106%, due to the evolution of operating costs and the main macroeconomic indicators.

Subsequently, on February 1, 2022, tgs received from ENARGAS a proposal for a Transitional Renegotiation Agreement (the “2022 Transition Agreement”) which was approved by our Board of Directors on February 2, 2022 and by the corresponding government agencies on February 18, 2022. The 2022 Transition Agreement includes, in some aspects, similar terms to the 2021 RTT with the particularity that it grants tgs a 60% tariff increase effective as from March 1, 2022 (the “RTT 2022”).

The 2022 Transition Agreement was ratified by the PEN through Decree No. 91/2022, which entered into force as from February 23, 2022. On February 25, 2022, the ENARGAS issued Resolution No. 60/2022 by which it put into effect the tariff schedules that contemplate the RTT 2022.

It should be noted that, in accordance with the provisions of the 2022 Transition Agreement, tgs committed not to initiate new claims, appeals, actions, lawsuits or demands of any kind; and/or to suspend, keep suspended or extend the suspension of all appeals and claims filed that are related in any way to the Renegotiation of the Comprehensive Tariff Review in force, Law No. 27,541, Decrees No. 278/20 and No. 1020. Under Decrees 1020 and 815, on December 7, 2022, ENARGAS issued Resolution No. 523/2022 which called for a public hearing on January 4, 2023 to, among other issues, consider the transitory adjustment of tariffs for the public natural gas transportation service.

As of the date of issuance of these Consolidated Financial Statements, the Company is working together with ENARGAS to carry out the RTI process that will allow it to receive a fair and reasonable tariff according to the natural gas transportation public service provided.

b) General Framework for non-regulated segments

Domestic market

The Production and Commercialization of Liquids segment is not subject to regulation by ENARGAS, and as it is provided in the Transfer Agreement, is organized as a separate business unit within tgs, keeping accounting information separately. However, over recent years, the Argentine Government enacted regulations which significantly impacted on it.

In April 2005, the Argentine Government enacted Law No. 26,020 which sets forth the regulatory framework for the industry and commercialization of LPG. Among other things, the Law No. 26,020 creates the framework through which the Secretary of Hydrocarbon Resources (“SHR”) (formerly the Federal Energy Bureau) establishes regulations meant to cause LPG suppliers to guarantee sufficient supply of LPG in the domestic market at low prices. Law No. 26,020 creates a price regime pursuant to which the SRH periodically publish reference prices for LPG sold in the domestic market. It also sets forth LPG volumes to be sold in the domestic market.

Within this framework, tgs sells propane and butane production to fractionators at prices determined every six months. On March 30, 2015, the Executive Branch issued Decree No. 470/2015, regulated by Resolution No. 49/2015 issued by the Federal Energy Bureau, which created the Programa Hogares con Garrafa (the “Households with Bottles Program”) which replaced the programs in force until that time. The Households with Bottles Program was implemented through Resolutions No. 49/2015 and No. 470/2015 issued by the Federal Energy Bureau.

Within the framework of the Households with Bottles Program, a maximum reference price was determined for the members of the commercialization chain in order to guarantee the supply to low-income residential users, forcing producers to supply with LPG at a certain price and at a certain quantity defined for each of them. Additionally, the payment of compensation to the participating producers of the Households with Bottles Program was established.

During 2020 and in accordance with Decree 311, the maximum reference prices for the commercialization of liquefied petroleum gas (LPG), which the Company sells in the domestic market, remained unchanged for a period of 180 calendar days from its issuance. On October 19, 2020, the Energy Secretariat issued Resolution 30/2020 by which it increased the price of such products to Ps. 10,885 (in accordance with the provisions of said resolution).

During 2021, the Secretary of Energy issued Resolution No. 249/2021 by which it increased the prices as from April 6, 2021 to Ps. 12,626.60 (in accordance with the provisions of said resolution).

During 2022, the SE, through Resolutions No. 270/2022 and 609/2022, ordered increases in the price of the products that are marketed within the framework of this program. The last one, as of September 2022, raised it to Ps.18,375.49 per ton (according to Resolution 609).

In this context, the Company has filed several administrative and judicial claims challenging the general regulations of the Home Plan, as well as the administrative acts that determine the volumes of butane to be sold in the local market, in order to safeguard its economic-financial situation and so that such situation does not continue in time.

Additionally, the Company participates in the Propane Gas Supply Agreement for Indiluted Propane Gas Distribution Networks (“Propane for Networks Agreement”) entered into with the Argentine Government and propane producing companies whereby it undertakes to supply propane to distributors and sub-distributors of indiluted propane gas through networks at a price lower than the market price, The Company receives an economic compensation for the lower revenues derived from the participation in this program, which is calculated as the difference between the agreed sales price and the reference export parity price determined by the Energy Secretariat.

Within the framework of the path of gradual reduction of subsidies provided by the former MINEM, on March 31, 2017 the former MINEM issued Resolutions No. 74/2017 (“Resolution 74”) and No. 474-E/2017 (“Resolution 474”) by which an increase in the price of indiluted propane gas destined to the Propane for Networks Agreement is provided as from April 1 and December 1, 2017, respectively. As from such dates the price paid by the customer was set at Ps. 1,267/tn and Ps. 2,832/tn (as provided by Resolution 74) and Ps. 1,941.20/tn and Ps. 3,964/tn (as provided by Resolution 474), respectively, depending on the customer to whom the product is destined.

Finally, in May 2018 tgs entered into the sixteenth extension to the Propane Agreement for Networks which served as a framework for the commercialization of the products stipulated therein for the period April 1, 2018 - December 31, 2019. Additionally, this last extension fixed the price at which the propane destined to this program was marketed to the customer. Notwithstanding the foregoing, on January 14, 2020 tgs received the instruction issued by the Secretary of Energy to proceed with the propane deliveries according to the conditions of the sixteenth extension of the Propane for Networks Agreement. Subsequently, the Company entered into the seventeenth extension to the Propane for Networks Agreement, effective until December 31, 2020. On August 10, 2021, tgs celebrated the eighteenth extension of the Propane Agreement for Networks, valid until December 31, 2021. On February 17, 2022, tgs celebrated the nineteenth extension of the Propane for Networks Agreement, valid until December 31, 2022.

As mentioned above, participation in the Plan Hogar implies economic-financial losses for the Company, since under certain circumstances the sale of the products would be made at prices below production costs.

As of December 31, 2022, the Argentine State owes tgs Ps. 3,768,159 for these concepts.

Foreign market

On September 3, 2018, the Executive Branch issued Decree No. 793/2018, which, between September 4, 2018 and December 31, 2020, sets an export duty of 12% on the exported amount of propane, butane and natural gasoline. This withholding is capped at $4 for each dollar of the tax base or the official FOB price.

Subsequently, on the occasion of the enactment of the Solidarity Law, an 8% cap was established for the rate applicable to hydrocarbons as of December 23, 2019.

Presidential Decree No. 488/2020 regulated the applicable tax rate on exports of certain oil and gas products, including those products that we export, establishing a range between 0% and 8% depending on the “ICE Brent first line” barrel price. If the price is below US$ 45, the tax rate will be zero percent . On the other hand, if the price is equal to or higher than US$ 60, an 8% tax rate will be paid, being variable if the price is between US$ 45 and US$ 60.

Decree No. 2,067 / 08

Through Presidential Decree No. 2,067/08, the Executive Branch created a tariff charge to be paid by: (i) the users of regulated services of transportation and / or distribution, (ii) natural gas consumers receiving natural gas directly from producers without making use of transportation systems or natural gas distribution, (iii) the natural gas processing companies in order to finance the import of natural gas. The tariff charge sets forth in this decree finance the higher price of the natural gas imports required to compensate the injection of natural gas necessary to meet national requirements (the “Charge”). When the Charge was created, tgs paid it in accordance with the provisions of Resolution I-563/2008, at Ps. 0.0492/m3.

The payment of the natural gas processing tariff charge was selectively subsidized from 2008 according to the destination of the natural gas. In November 2011, however, ENARGAS issued Resolution No. 1,982/11 and 1,991/11 (the “Subsidy Beneficiaries Resolutions”) which modified the list of the subsidy beneficiaries, and thus, involved a cost increase for many of our clients and for us (for certain of our consumption for our own account). The natural gas processing tariff charge increased from Ps. 0.0492 to Ps. 0.405 per cubic meter of natural gas effective from December 1, 2011, representing a significant increase in our variable costs of natural gas processing.

In order to avoid this damage, tgs appealed against the Presidential Decree and the Resolutions including National Government, ENARGAS and ex MPFIPyS as defendants.

For further information regarding the legal action filed the Company, see Note 20.b).

On March 28, 2016, the former MINEM issued Resolution No. 28/16 (“Resolution 28”), which instructs ENARGAS to take all the necessary measures to derogate the tariff charge created by Decree No. 2,067/08 as from April 1, 2016. However, such Resolution does not repeal or declare illegitimate this decree and the Subsidy Beneficiaries Resolutions for which the judicial action is still ongoing.

c) Essential assets

A substantial portion of the assets transferred by GdE has been defined as essential for the performance of the natural gas transportation service. Therefore, tgs is required to keep separated and maintain these assets, together with any future improvements, in accordance with certain standards defined in the License.

tgs may not, for any reason, dispose of, encumber, lease, sublease or loan essential assets nor use such assets for purposes other than the provision of the licensed service without ENARGAS´s prior authorization. Any expansion or improvements that it makes to the gas pipeline system may only be encumbered to secure loans that have a term of more than one year to finance such extensions or improvements.

Upon expiration of the License, tgs will be required to transfer to the Argentine government or its designee, the essential assets listed in an updated inventory as of the expiration date, free of any debt, encumbrances or attachments. If the Company decides not to continue with the license, tgs will receive a compensation equal to the lower of the following two amounts:

i) The net book value of the essential assets determined on the basis of the price paid by the acquiring joint arrangements, and the original cost of subsequent investments carried in US dollars and adjusted by the PPI, net of accumulated depreciation according to the calculation rules to be determined by ENARGAS; or

ii) The net proceeds of a new competitive bidding (the “New Bidding”).

Once the period of the extension of the License expires, tgs will be entitled to participate in the New Bidding, and thus, it shall be entitled to:

(i) That its bid in the New Bidding be computed at an equal to the appraisal value to be determined by an investment bank selected by ENARGAS, which represents the value of the business of providing the licensed service as it is driven by the Licensee at the valuation date, as a going concern and without regard to the debts;

(ii) To obtain the new License, without payment, in the event that any bid submitted in the New Bidding exceeds the appraised value;

(iii) To match the best bid submitted by third parties in the New Bidding, if it would be higher than its bid mentioned in (i), paying the difference between both values ​​to obtain the new License;

(iv) If the Company is unwilling to match the best bid made by a third party, to receive the appraisal value mentioned in (i) as compensation for the transfer of the Essential Assets to the new licensee.

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ASSETS AND LIABILITIES IN FORREIGN CURRENCY

12 Months Ended

Dec. 31, 2022

ASSETS AND LIABILITIES IN FORREIGN CURRENCY [Abstract]

ASSETS AND LIABILITIES IN FORREIGN CURRENCY

18. ASSETS AND LIABILITIES IN FORREIGN CURRENCY

The balances in foreign currency as of December 31, 2022 and 2021 are detailed below:

	2022							2021
	Foreign currency					Amount		Foreign currency		Amount
	and amount		Exchange			in local		and amount		in local
	(in thousands)		rate			currency		(in thousands)		currency
CURRENT ASSETS
Cash and cash equivalents	US$	1,613		176.960	(1)		285,436	US$	1,512		301,949
Financial assets at fair value through profit or loss (3)	US$	176,852		176.960	(1)		31,295,730		65,522		13,084,872
Trade receivables	US$	66,107		176.960	(1)		11,698,295	US$	66,395		13,259,212
Total current assets	US$	244,572					43,279,461	US$	133,429		26,646,033
NON CURRENT ASSETS
Financial assets at amortized cost (4)	US$	226,957		176.960	(1)		40,162,283	US$	218,917		43,718,092
Total non current assets	US$	226,957					40,162,283	US$	218,917		43,718,092
TOTAL ASSETS	US$	471,529					83,441,744	US$	352,346		70,364,125
CURRENT LIABILITIES
Trade payables	US$	38,655		177.160	(2)		6,848,120	US$	37,807		7,564,861
	Euros	432		189.916	(2)		82,043		-		-
Loans	US$	21,819		177.160	(2)		3,865,516	US$	11,493		2,299,738
	Euros	287		189.916	(2)		54,413		-		-
Total current liabilities	US$	60,474					10,713,636	US$	49,300		9,864,599
	Euros	719					136,456		-		-
NON CURRENT LIABILITIES
Loans	US$	511,933		177.160	(2)		90,694,136	US$	500,377		100,121,274
Contract liabilities	US$	10,106		177.160	(2)		1,790,361		-		-
Total non current liabilities	US$	522,039					92,484,497	US$	500,377		100,121,274
TOTAL LIABILITIES	US$	582,513					103,198,133	US$	549,677		109,985,873
	Euros	719					136,456		-		-

⁽¹⁾ Buy exchange rate at the end of fiscal year

⁽²⁾ Sell exchange rate at the end of fiscal year

⁽³⁾ Includes public and private debt bonds Dólar Linked for Ps. 27,013,330.

⁽⁴⁾ Includes time deposits Dólar Linked for Ps. 865,009.

US$: United States of America dollars

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COMMON STOCK AND DIVIDENDS

12 Months Ended

Dec. 31, 2022

COMMON STOCK AND DIVIDENDS [Abstract]

COMMON STOCK AND DIVIDENDS

19. COMMON STOCK AND DIVIDENDS

a) Common stock structure and shares’ public offer

As of December 31, 2022, 2021 and 2020, tgs’ common stock was as follows:

Common Stock structure as of December 31, 2022, 2021 and 2020
Shares Class	Amount of common stock, subscribed, issued, paid in, and authorized for
	public offer
Common Shares Class
(Face value $ 1, 1 vote)	Outstandings shares		Treasury Shares		Common Stock
Class “A”		405,192,594		-		405,192,594
Class “B”		347,568,464		41,734,225		389,302,689
Total		752,761,058		41,734,225		794,495,283

tgs’s shares are traded on the BYMA and under the form of the American Depositary Receipts (“ADS”) (registered in the SEC and representing 5 shares each) on the New York Stock Exchange.

b) Acquisition of treasury shares

On March 6, 2020, the Company’s Board of Directors approved the sixth Program for the Acquisition of tgs treasury Shares in the markets where it makes a public offering of its shares (the “Sixth Repurchase Program”) for a maximum amount of Ps. 2,500 million (at the time of its creation).

Subsequently, on August 21, 2020, the Board of Directors approved a new Program for the Acquisition of tgs’ treasury Shares for a maximum amount to be invested in Ps. 3,000 million (at the time of its creation). This program will run until March 22, 2021.

The acquisition cost of the treasury shares in portfolio amounted to Ps. 10,924,539, which, together with the trading premium on treasury shares of Ps. 3,169,112, in accordance with the provisions of Title IV, Chapter III, article 3.11.c and e of the Rules, restricts the amount of realized and liquid gains that the Company may distribute.

c) Restrictions on distribution of retained earnings

Pursuant to the General Companies Act and CNV Rules, we are required to allocate a legal reserve (“Legal Reserve”) equal to at least 5% of each year’s net income (as long as there are no losses for prior fiscal years pending to be absorbed) until the aggregate amount of such reserve equals 20% of the sum of (i) “common stock nominal value” plus (ii) “inflation adjustment to common stock,” as shown in our consolidated statement of changes in equity.

Finally, and as mentioned in subsection b of this note, the amounts subject to distribution are restricted up to the acquisition cost of treasury shares and the paid-up capital.

In addition, according with the 2022 Transitional Agreement, tgs may not distribute dividends meanwhile it will be in force.

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LEGAL CLAIMS AND OTHER MATTERS

12 Months Ended

Dec. 31, 2022

LEGAL CLAIMS AND OTHER MATTERS [Abstract]

LEGAL CLAIMS AND OTHER MATTERS

20. LEGAL CLAIMS AND OTHER MATTERS

a) Turnover tax calculated on the natural gas price consumed by tgs

The Company has interpretative differences with several provinces regarding the liquidation of the turnover tax calculated on the natural gas used by tgs as fuel to render its transportation services. In this framework there have been initiated several lawsuits against tgs, which have adversely concluded by the Company.

As of December 31, 2022 and 2021, the Company has recorded a provision for these concepts of Ps. 1,657.4 million and Ps. 2,210.7 million, respectively, recorded in the caption “Provisions”, determined based on the estimated tax and interest payable as of such date, in the event that these claims from the provinces are unfavorable for tgs.

b) Action for annulment of ENARGAS Resolutions No. I-1,982/11 and No. I-1,991/11 (the “Resolutions”)

After the issuance of the Resolutions, tgs filed a judicial action before the National Court of First Instance in Federal Administrative Litigation No. 1 (the “Court”) in order to obtain the declaration of nullity of the Presidential Decree No. 2067/08 and the Resolutions as well as the unconstitutionality of the administrative acts that created the Charge.

On July 5, 2012, the Court issued in favor of tgs a precautionary measure by which the suspension of the Charge was ordered in the terms set forth in the Resolutions. This decision was appealed in different opportunities by the National Government, by virtue of which the dictating of the precautionary measure was limited to the validity of six months. However, at maturity, the Company is entitled to obtain a new precautionary measure for a similar period.

As a result, on September 19, 2017, a new extension of the injunction was obtained (which prevented the Government to claim tgs of the payment of the amounts resulting from the new value of the Charge for the period between the November 2011 and March 2016), thus extending the validity until March 2018.

On the other hand, the National Court of Appeals in Contentious Administrative Dismissal rejected the extraordinary appeal filed by the National Government against the judgment of that court that confirmed the rejection made by the Court at the request of ENARGAS to declare abstract the legal action initiated by tgs in accordance with the precedent “Alliance” issued by the Supreme Court in December 2014.

On March 26, 2019, tgs was notified of the judgment of first instance issued by the Federal Contentious-Administrative Court No. 1 in its claim initiated by which tgs requested the unconstitutionality of Decree No. 2,067/08; Resolutions and of any other rule or act issued or to be issued, that is caused by the mentioned rules (the “Cause”).

The first instance judgment declares the unconstitutionality of both Articles 53 and 54 of Law 26,784, as well as the aforementioned rules and of any other act tending to execute said provision, and consequently, the nullity of said rules (the “sentence”).

The Judgment was appealed by the National Government on March 29, 2019, and the appeal was granted on April 3, 2019, which has not been resolved as of the closing date of the year.

On October 29, 2019, the intervening judge decided, considering what was decided in the judgment and attending to the reasons invoked by tgs, to extend the validity of the precautionary measure issued for six more months of processing in said ordinary process and / or until the sentence passed is firm.

Pursuant to the isolation measures adopted by the Argentine Government under the COVID development, the judicial deadlines were suspended from March 20, 2020 until July 21, 2020. Considering that the six-month term should not be computed during fair periods, the remaining term of 2 months and 9 days was completed on September 29, 2020.

On December 1, 2020, the court granted a new extension of said injunction for a term of 6 months.

On May 14, 2021, tgs was notified of the ruling issued by Chamber I of the Chamber in Contentious-Administrative Matters that (i) has revoked the decision by the Judge of First Instance and (ii) has imposed the costs in both instances in the order caused. tgs considers that it has reasonable arguments to defend its position on the substantive issue raised and, for that reason, it appealed the judgment of the Chamber.

On June 4, 2021, tgs filed an extraordinary federal appeal against the judgment of the Chamber, which was contested by ENARGAS and the National State, and was granted by the Court of Appeals itself on July 14, 2021, on the understanding that “At stake is the interpretation and scope of regulations of an unquestionable federal nature, such as Decree 2067/08 and MINPLAN Resolution No. 1451/2008, ENARGAS Resolutions No. 1982/11 and 1991/11, as well as articles 53 and 54 of Law 26,784”.

By virtue of the precautionary measure issued, and its 12 extensions obtained, as well as the favorable judgment obtained in the first instance, the existence of favorable precedents issued by the Supreme Court of Justice of the Nation (“Supreme Court”) with respect to other processors of natural gas and the granting of the extraordinary appeal that will give rise to the Supreme Court ruling on the case, the management of tgs and its legal advisors consider that they have solid arguments to defend their position and that it is probable that a favorable resolution will be obtained for their interests on the substantive issue raised. Therefore, no provision has been made for the eventual liabilitie due to the increase in the charge to finance the importation of natural gas applicable to natural gas consumption related to the processing activity at the Cerri Complex for the period between the date of obtaining the measure precautionary and on April 1, 2016, date of entry into force of Resolution No. 28/2016.

This resolution has annulled the acts that determined the value of the charge established by Decree 2067, for which as of April 1, 2016, ENARGAS and the agency in charge of its collection have stopped charging the increase established by the Resolutions.

Regarding the last extension of the precautionary measure, expired on July 1, 2021, tgs has not requested a new extension, due to the premature procedural stage in which the appeal filed against the judgment of the Chamber is found.

Given the complex procedural instance, the nature of charge 2067, the background information presented in this and other legal cases initiated against charge 2067, at the date of the issuance of these Consolidated Financial Statements it is not possible to make a definitive quantification of the amount that should be pay tgs in the event of not obtaining a favorable ruling from the Supreme Court, while an eventual request for payment in the current circumstances may be challenged and questioned by tgs within the framework of the corresponding administrative and judicial instances, where the amount may be debated of the charge that is eventually required to tgs.

c) Recovery action of VAT and income tax

On October 9, 2008, tgs signed the 2008 Transitional Agreement with ex UNIREN that contemplated a tariff increase of 20%, applicable as from September 1, 2008. On December 3, 2009, the Executive Branch ratified this transitional agreement through the Presidential Decree No. 1,918/09. By means of this decree, tgs was able to bill the tariff increase to its clients as soon as ENARGAS would have published the new tariffs schedule and set the methodology to bill the retroactive effect. Finally, this administrative act did not become effective and therefore in September 2010 tgs filed an acción de amparo (a summary proceeding to guarantee constitutional rights). Due to the passing of time since the enactment of Decree No. 1918/09, on December 16, 2010, the Board of Directors of the Company resolved to discontinue the recognition of the tariff increase revenue and to reverse the receivable of the tariff increase revenue already accrued. The reversal of the tariff increase did not imply any resignation to the Company´s rights resulting from the Decree No. 1,918/09.

On May 24, 2013, tgs filed a tax recovery appeal with respect to the income tax and VAT credits generated by the reversal of the tariff increase credit mentioned above. The total amount claimed by tgs amounted to Ps. 102.5 million plus compensatory interests. After the omission to pass judgment on the claim within the three months of the filing of the tax recovery appeal, on October 9, 2013, tgs filed an appeal before the Federal Tax Bureau. On June 6, 2017, the Tax Court of the Nation rejected the claim for recovery filed by the Company. This resolution was appealed by tgs.

On May 7, 2019, the National Court of Appeals for Federal Administrative Disputes made the appeal filed by tgs and revoked the judgment of first instance, with costs to the defeated defendant. On May 23, 2019, the Treasury filed an Extraordinary Appeal - which was granted on September 26, 2019 in relation to the interpretation of the federal norms at stake in the case, but was denied as to the arbitrariness of judgment - and then Complaint Appeal.

On August 5, 2021, the Supreme Court confirmed the ruling of Chamber I of the Federal Contentious-Administrative Chamber in favor of tgs, which is final.

After having made the corresponding presentations before the AFIP, the Company proceeded to offset the credit (capital plus interest) generated with the payment of taxes as established by the tax agency.

d) Turnover tax withholding in the Province of Buenos Aires

The Company was notified by ARBA regarding the initiation of various determinative procedures in which tgs is claimed for a total of Ps. 4.9 million (without fine or interest) for the omission as agent of withholding and collection of the turnover tax corresponding to the period July 2009 - June 2011. Given this determination, the Company presented to ARBA various elements of evidence that allow reducing substantially the amount claimed. As of the date of issuance of these consolidated financial statements, the Tax Court has not resolved the issue.

In March 2017, tgs partially canceled the debt claimed by ARBA, paying Ps. 2.9 million (stated in its original value) through the adhesion to the payment plans offered by the Province of Buenos Aires through Law 14,890. Adherence to these payment plans allowed partial cancellation of compensatory interest and all fines and charges claimed by ARBA.

As of the date of the issuance of these Consolidated Financial Statements, only two files remain in relation to the alleged failure of tgs to act as withholding and collection agent during 2009 and 2010. The Company’s Management considers that it has sufficient arguments to assert its defense so at December 31, 2022 and 2021 and no provisions have been recorded for this concept.

e) Environmental matters

The Company is subject to extensive environmental regulations in Argentina. Management believes that its current operations are in material compliance with applicable environmental requirements, as currently interpreted and enforced. The Company has not incurred in any material environmental liabilities as a result of its operations to date. As of December 31, 2022 and 2021, the total amount of these provisions amounted Ps. 58.5 million and 92.3 million, respectively.

f) Others

In addition to the matters discussed above, the Company is a party to certain lawsuits and administrative proceedings which involve taxation, labor claims, social security, administrative and others arising in the ordinary course of business. The Company’s Management and its legal advisors estimate that the outcome of these differences will not have significant adverse effects on the Company’s financial position or results of operations. As of December 31, 2022 and 2021, the total amount of these provisions amounted Ps. 77.4 million and Ps. 221.5 million, respectively

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BALANCES AND TRANSACTIONS WITH RELATED COMPANIES

12 Months Ended

Dec. 31, 2022

BALANCES AND TRANSACTIONS WITH RELATED COMPANIES [Abstract]

BALANCES AND TRANSACTIONS WITH RELATED COMPANIES

21. BALANCES AND TRANSACTIONS WITH RELATED COMPANIES

Technical, Financial and Operational Assistance Agreement

Pampa Energía is tgs’s technical operator, according to the approval of ENARGAS in June 2004, and subject to the terms and conditions of the Technical Assistance Agreement which provides that Pampa Energía is in charge of providing services related to the operation and maintenance of the natural gas transportation system and related facilities and equipment, to ensure that the performance of the system is in conformity with international standards and in compliance with certain environmental standards. For these services, the Company pays a monthly fee based on a percentage of the operating income of the Company.

The Ordinary and Extraordinary General Shareholders´ Meeting held on October 17, 2019 ratified the proposal approved by the Board of Directors at its meeting on September 17, 2019 made to Pampa Energía that implies an extension in the contract and a modification in the determination of the remuneration received by Pampa Energía.

Such modifications, without implying a modification in the scope of the tasks performed, will mean a progressive reduction over the years in the remuneration that Pampa Energía will receive in its role of Technical Operator.

According to the modifications made, tgs will pay Pampa Energía the greater of: (i) an annual fixed sum of US$ 0.5 million or (ii) the variable compensation that arises from applying to comprehensive income before results and income taxes for the year but after deducting also the above fixed amount) the following scheme:

• From 12/28/2019 to 12/27/2020: 6.5%

• From 12/28/2020 to 12/27/2021: 6%

• From 12/28/2021 to 12/27/2022: 5.5%

• From 12/28/2022 to 12/27/2023: 5%

• From 12/28/2023 to 12/27/2024 and onwards: 4.5%

Commercial transactions

In the normal course of its activity, tgs celebrated with Pampa Energía and other companies related to it, agreements to transfer natural gas and its richness. The price, which is denominated in US dollars, is determined according to common market practices.

In addition, in the normal course of business, tgs carries out liquid sales, natural gas transportation services and other services with its associated companies, Pampa Energía and related companies.

Financial lease agreement with Pampa Energía

As mentioned in Note 13 to these Consolidated Financial Statements, on August 11, 2016, the Company entered into a finance lease agreement with Pampa Energía (formerly Petrobras Argentina).

Key management compensation

The accrued amounts corresponding to the compensation of the members of the Board of Directors, the Statutory Committee and the Executive Committee for the years ended December 31, 2022, 2021 and 2020 were Ps. 427,015, Ps. 400,832 and Ps. 406,894, respectively.

Balances and transactions with related parties

The detail of significant outstanding balances for transactions entered into by tgs and its related parties as of December 31, 2022 and 2021 is as follows:

	2022				2021
Company	Accounts receivable		Accounts payable		Accounts receivable		Accounts payable
Controlling shareholder:
CIESA		37		-		-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía (1)		1,299,505		4,889,458		659,046		6,830,195
Associate which exercises significant influence on the controlling shareholder:
Link		4,683		-		5,088		-
TGU		-		28,199		-		31,849
Other related companies:
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		19,695		17,518		24,165		35,932
CT Barragán S.A.		4,294		-		7,385		-
SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A.		2,227		-		-		-
Transener S.A.		30		-		-		61
Total		1,330,471		4,935,175		695,684		6,898,037

⁽¹⁾ Accounts payable includes Ps. 4,262,215 and Ps. 5,887,648 corresponding to the financial leasing recorded as “Loans” as of December 31, 2022 and 2021, respectively.

Additionally, during the year ended December 31, 2022, the Company received from SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A., construction engineering services for Ps. 3,318,934 which are activated within the balance of advances to suppliers.

As of December 31, 2022 and 2021, tgs has a balance of Ps. 2,570,796 and Ps. 1,388,558 corresponding to Dollar linked notes issued by CT Barragán S.A. that accrue an annual rate of 4% over the exchange rate established in BCRA Communication “A” 3500 and that amortize the entire capital in June 2023, November 2024 and May 2025. The book value of the notes is disclosed within the caption “Financial assets at fair value through profit or loss”.

The detail of significant transactions with related parties for the years ended December 31, 2022, 2021 and 2020 is as follows:

Year ended December 31, 2022:

			Revenues				Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense		Interest gain / Gain / (loss) on fair value	Selling expenses (1)
Controlling shareholder:
CIESA		-		-		-		-		-		-		162	-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		1,471,413		3,583,230		3,972,829		5,826,231		3,067,198		-		-	-		-
Associates with significant influence:
Link		-		-		46,750		-		-		-		-	-		-
Other related companies:
SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A.		-		-		7,203		-		-		-		-	-		-
Transener S.A.		-		-		417		-		-		-		-	-		-
CT Barragán S.A.		-		-		17,459		-		-		-		-	96,408		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		298,568		-		-		-		-		-		-	-		-
Fundación TGS		-		-		-		-		-		-		-	-		31,059
Total		1,769,981		3,583,230		4,044,658		5,826,231		3,067,198		-		162	96,408		31,059

⁽¹⁾ Corresponds to donations expenses.

Year ended December 31, 2021:

			Revenues				Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense		Interest gain / Gain / (loss) on fair value		Selling expenses (1)
Controlling shareholder:
CIESA		-		-		-		-		-		277		-		-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		1,666,555		4,996,215		2,365,465		5,628,181		4,250,358		-		568,315		-		-
Associates with significant influence:
Link		-		-		-		-		-		-		-		-		-
Other related companies:
Oleoductos del Valle S.A.		51,542		-		54,102		-		-		-		-		-		-
Transener S.A.		-		-		701		-		-		-		-		-		-
CT Barragán S.A.		-		-		26,659		-		-		-		-		484,082		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		289,761		-		-		-		-		-		-		-		-
Fundación TGS		-		-		-		-		-		-		-		-		2,277
Total		2,007,858		4,996,215		2,446,927		5,628,181		4,250,358		277		568,315		484,082		2,277

⁽¹⁾ Corresponds to donations expenses.

Year ended December 31, 2020:

	Revenues						Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense
Controlling shareholder:
CIESA		-		-		-		-		-		411		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		2,473,548		3,087,152		1,807,202		470,636		4,205,901		-		712,528
Associates with significant influence:
Link		-		-		57,517		-		-		-		-
Other related companies:
Oleoductos del Valle S.A.		75,765		-		-		-		-		-		-
Transener S.A.		-		-		1,034		-		-		-		-
Petrolera Entre Lomas S.A.		7,277		-		26,268		-		-		-		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		331,583		-		-		-		-		-		-
Central Térmica Piedrabuena S.A.		5,131		-		-		-		-		-		-
Total		2,893,304		3,087,152		1,892,020		470,636		4,205,901		411		712,528

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CONTRACTUAL OBLIGATIONS

12 Months Ended

Dec. 31, 2022

CONTRACTUAL OBLIGATIONS [Abstract]

CONTRACTUAL OBLIGATIONS

22. CONTRACTUAL OBLIGATIONS

a) Contractual Commitments

As of December 31, 2022, the Company had the following contractual commitments:

	Estimated maturity date
	Total		Due less than one year		As of 12/31/2023		From 01/01/2024 to 12/31/2024		From 01/01/2025 to 12/31/2025		From 01/01/2026 to 12/31/2026
Financial indebtedness (1)		109,769,494		-		7,848,106		10,351,813		91,569,575		-
Purchase obligations (2)		18,144,797		-		16,289,422		1,855,375		-		-
Financial Leases		4,901,101		133,549		1,325,156		1,325,334		1,325,334		791,728
Total		132,815,392		133,549		25,462,684		13,532,522		92,894,909		791,728

⁽¹⁾ Corresponds to the cancellation of principal and interest of the financial indebtedness. For further information, see Note 13.

⁽²⁾ Corresponds to purchase of natural gas contracts for the processing of liquids.

The totality of the financial indebtedness of tgs and the obligations corresponding to gas purchases are denominated in U.S. dollars which have been translated into Argentine pesos at the exchange rate as of December 31, 2022 (US$ 1.00 = Ps. 177.16). The amounts to be paid in pesos could vary depending on the actual fluctuations in the exchange rate.

b) Guarantees granted and goods for restricted availability

The Company has not granted any additional guarantees or goods of restricted availability other than those set out in the remaining notes.

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ASSOCIATES AND JOINT ARRANGEMENTS

12 Months Ended

Dec. 31, 2022

ASSOCIATES AND JOINT ARRANGEMENTS [Abstract]

ASSOCIATES AND JOINT ARRANGEMENTS

23. ASSOCIATES AND JOINT ARRANGEMENTS

Link:

Link was created in February 2001, with the purpose of the operation of a natural gas transportation system, which links tgs’s natural gas transportation system with the Cruz del Sur S.A. pipeline. The connection pipeline extends from Buchanan, located in the high-pressure ring that surrounds the city of Buenos Aires, which is part of tgs’s pipeline system, to Punta Lara. tgs’s ownership interest in such company is 49%, while Pan American Sur S.A. holds a 20.40%, Shell Argentina S.A. a 25.50% and Wintershall Dea Argentina S.A. the remaining 5.10%.

On December 29, 2021, Link paid a cash dividend for Ps. 181,984.

TGU:

TGU is a company incorporated in Uruguay. This company rendered operation and maintenance services to Gasoducto Cruz del Sur S.A. and its contract terminated in 2010. tgs holds 49% of its common stock and Pampa Energía holds the remaining 51%.

EGS (in liquidation):

In September 2003, EGS, a company registered in Argentina, was incorporated. The ownership is distributed between tgs (49%) and TGU (51%).

EGS owned a natural gas pipeline, which connects tgs’s main pipeline system in the Province of Santa Cruz with a delivery point on the border with Chile.

In October 2012, ENARGAS issued a resolution which authorizes EGS to transfer the connection pipeline and service offerings in operation to tgs. On November 13, 2013, the sale of all the fixed assets of EGS to tgs for an amount of US$ 350,000 was made, the existing natural gas transportation contracts were transferred and the procedures to dissolve the Company were initiated.

The Board of Directors Meeting held on January 13, 2016, approved to initiate the necessary steps for the dissolution of EGS. The Special Shareholders Meeting held on March 10, 2016 appointed EGS’ liquidator.

Joint Agreement

UT:

The Board of Directors of tgs approved the agreement to set up the UT together with SACDE. The objective of the UT is the assembly of pipes for the construction of the project of “Expansion of the System of Transportation and Distribution of Natural Gas” in the Province of Santa Fe, called by National Public Bid No. 452-0004-LPU17 by the MINEM (the “Work”).

On October 27, 2017, tgs - SACDE UT signed the corresponding work contract with the MINEM.

The UT will remain in force until its purpose has been fulfilled, i.e., once the works involved in the Project have been completed and until the end of the guarantee period, set at 18 months from the provisional reception.

As a result of the situation of the economic context and COVID mentioned in Note 1, the UT sent a letter to Integración Energética Argentina S.A., a company currently part of the Ministry of Productive Development, requesting, among other issues, the reestablishment of the economic-financial equation, readjustment of the Work schedule, approval of cost redeterminations and price adjustments under the current legal regime. The parties are currently engaged in a detailed calculation of the items involved in the claim. In this regard, the UT has only carried out essential tasks, pending approval of a construction schedule appropriate to the actual execution of the works. The Company does not consider that there will be significant negative effects derived from this request to the Argentine Government.

On July 9, 2021, the UT and IEASA signed an order to restart the work related to the Project, through which the work schedule was readjusted and IEASA also assumed the commitment to manage and join efforts to guarantee the cash flow in order to avoid new effects on the economic-financial structure of the Works contract, which would give rise to new requests -by the UT- to recompose the economic-financial equation of the contract and the schedule of execution of the Work.

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SUBSEQUENT EVENTS

12 Months Ended

Dec. 31, 2022

SUBSEQUENT EVENTS [Abstract]

SUBSEQUENT EVENTS

24. SUBSEQUENT EVENTS

The financial statements were authorized for issuance by the Board of Directors on April 25, 2023. There are no subsequent events between the closing date of year ended December 31, 2022, and the approval (issuance) of these consolidated financial statements, other than the ones already disclosed therein.

Natural gas transportation transitional tariff increase

On March 16, 2023, tgs’ Board of Directors approved the proposed addendum to the renegotiation transitory agreement (the “2023 transition agreement”) sent by ENARGAS. As of the date of issuance of these Financial Statements the 2023 transition agreement has not been ratified by the PEN.

The 2023 transition agreement has similar conditions to the 2022 Transition Agreement. The 2023 Transition Agreement includes:

-
A transitional tariff increase of 95% on the natural gas transportation tariff and the Access and Use Charge.

-
With prior authorization from the Ministry of Economy, tgs is allowed to distribute dividends and to directly or indirectly prepay financial and commercial debts contracted with shareholders. Previously prohibited by the 2022 Agreement.

Annual Ordinary Shareholders’ Meeting

Allocation of 2022’s net income and retained earnings

On April 19, 2023, the Annual Ordinary Shareholders’ Meeting (the “2023 Shareholders´ Meeting”) approved the increase in the legal reserve of Ps. 1,967 million and the allocation of Ps. 185,004 million to the reserve for capital expenditures, acquisition of treasury shares and/or dividends (the “Reserve”). The Board of Directors can release the Reserve to tgs’ shareholders for such purposes.

It is noteworthy that the above-mentioned decisions made by the 2023 Shareholders’ Meeting were taken considering current CNV regulations (Resolution No. 777/2018) which states retained earnings have to be adjusted by inflation using the rates as of the month before the meeting was held. In case of 2022 Shareholders’ Meeting, tgs used the inflation rate as of March 31, 2023.

2017 Program

The 2023 Shareholders´ Meeting approved the increase from US$ 1,200 million to US$ 2,000 million of the 2017 Program. As of the date of issuance of this Consolidated Financial Statements the Company is preparing all the documents to be filed to the CNV in order to obtain the above-mentioned authorization and the extension of the 2017 Program which expires on January 3, 2024.

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SIGNIFICANT ACCOUNTING POLICIES (Policies)

12 Months Ended

Dec. 31, 2022

SIGNIFICANT ACCOUNTING POLICIES [Abstract]

New accounting standards

4.a) New accounting standards

4.a 1) New standards and interpretations issued by the IASB effective for the years beginning on or after January 1, 2022 adopted by the Company

The new accounting standards, amendments and interpretations issued by the IASB that became effective as of January 1, 2022 and that have not had an impact on the Company’s consolidated financial statements are the following:

IAS 16 - Property, plant and equipment (“PPE”) – Proceeds before intended use

In May 2020, the IASB issued an amendment to IAS 16 that prohibits entities from deducting from the cost of an item of PPE the revenue from the sale of items produced while bringing that asset into use. Instead, an entity shall recognize the revenue from the sale of such items, as well as the costs of production of those items, in profit or loss.

This amendment became effective for annual periods that began on or after January 1, 2022 and should be applied retrospectively to items of PPE that are available for use from the beginning of the earliest period presented when the company first applies the amendment.

The amendments did not have a significant impact on the Company’s consolidated financial statements.

IAS 37: Onerous Contracts: Cost of Fulfilling a Contract

In May 2020, the IASB issued amendments to IAS 37 to specify which costs an entit should include when assessing whether a contract is onerous.

These amendments clarify the meaning of “costs to fulfill a contract”. Costs that relate directly to a contract for the supply of goods or services include both incremental costs and an allocation of costs directly related to contract activities.

These amendments became effective for annual reporting periods that began on or after January 1, 2022.

The amendments did not have a significant impact on the Company´s consolidated financial statements.

4.a.2) New IFRS issued that are not yet effective for the year beginning January 1, 2022.

The IFRS that potentially have an impact on the Company, which are not mandatory and have not been adopted early in the year beginning January 1, 2022, are listed below:

Classification of debt as current and non-current (amendment to IAS 1)

On January 23, 2020, the IASB issued the classification of debt as current and non-current, which amends IAS 1 Presentation of Financial Statements. These amendments affect the requirements of IAS 1 for the presentation of debt.

Specifically, it clarifies the criteria for classifying debt as non-current. The date of application of the amendment was set for fiscal years beginning on or after January 1, 2023, with retroactive application. The Company is evaluating the impact of these amendments for the presentation of debt.

IAS 12: “Income tax”

IAS 12 - Income Tax specifies how an entity accounts for income tax, including deferred tax, which represents tax to be paid or recovered in future periods.

The amendments clarify that the exemption defined in the standard to recognize deferred taxes when assets or liabilities are recognized for the first time is not applicable in the case of leases and provisions for decommissioning.

The amendments are effective for annual reporting periods beginning on or after January 1, 2023 and early application is permitted.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

IAS 8: “Accounting Policies, Changes in Accounting Estimates and Errors”

In February 2021, the IASB issued amendments to IAS 8, introducing a definition of “accounting estimates”. The amendments clarify the distinction between changes in accounting estimates and changes in accounting policies and the correction of errors. They also clarify how entities use measurement techniques and inputs to develop accounting estimates.

The modifications are effective for annual reporting periods that began on or after January 1, 2023.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

IAS 1: Disclosure of accounting policies – Practice Statement 2

In February 2021, the IASB issued amendments to IAS 1 and IFRS Practice Statement 2, Making Materiality, providing guidance and examples to help entities apply disclosure materiality judgments on accounting policies. The purpose of the amendments is to help entities provide information about accounting policies that is more useful, by replacing the requirement that entities disclose their “significant” accounting policies with “material” accounting policies and by adding guidance on how Entities apply the concept of materiality when making decisions about disclosures regarding accounting policies.

The modifications are effective for annual reporting periods that began on or after January 1, 2023.

This amendment is not expected to have a significant impact on the Company´s consolidated financial statements.

Consolidation

4.b) Consolidation

4.b.1) Subsidiaries

Subsidiaries are all entities over which the Company has control. The Company controls an entity when the Company is exposed to, or has rights to, variable returns from its involvement and has the ability to affect those returns through its power over the entity. Subsidiaries are fully consolidated from the date on which control is transferred to the group. They are deconsolidated from the date that control ceases. For this purpose and unless there are specific requirements, it is generally considered that tgs has control, when it has a participation equal to or greater than 50% of the available voting rights.

The accounting policies of the subsidiaries are consistent with the accounting policies adopted by the Company.

Inter-company transactions, balances and profit or loss from transactions between group companies are eliminated. Unrealized profit or loss are also eliminated.

Detailed data reflecting subsidiary control as of December 31, 2022 and 2021 is as follows:

		% of shareholding and voting
Company	Incorporation country	Direct			Indirect			Closing date	Main activity
Telcosur	Argentina		99.98	%		-		December 31	Telecommunication Services
CTG	Argentina		100	%		-		December 31	Electricity related services
TGSLatam	Bolivia		80	%		100	%	December 31	Hydrocarbons and Electrical power related services

For consolidation purposes for the year ended December 31, 2022, the financial statements of Telcosur and TGSLatam have been used at those dates. The subsidiary CTG does not record operations or significant assets and liabilities as of December 31, 2022 and 2021.

4.b.2) Associates

Associates are entities over which the group has significant influence but not control, generally accompanying a shareholding of between 20% and 50% of the voting rights. Investments in associates are accounted for using the equity method of accounting. Under the equity method, the investment is initially recognized at cost, and the carrying amount is increased or decreased to recognize the investor’s share of the profit or loss of the investee after the date of acquisition.

The Company accounted for the investments in its associates, under the equity method on the basis on the financial statements as of September 30, 2022 of Gas Link S.A. (“Link”), Transporte y Servicios de Gas en Uruguay SA (“TGU”) and Emprendimientos de Gas del Sur S.A. (“EGS”), under liquidation. Accounting policies of associates have been changed where necessary to ensure consistency with the policies adopted by the Company. The Company’s management is not aware of any significant subsequent events which affected the financial statements as of September 30, 2022 of Link, TGU and EGS (in liquidation) from this date to December 31, 2022.

Unrealized gains and losses resulting from transactions between tgs and the associate or joint venture are eliminated to the extent of the interest in the associate or joint venture.

In the table below, associates are disclosed, together with the percentage of shareholding and voting as of December 31, 2022 and 2021:

Company	% of shareholding and voting	Country	Main activity	Closing date
TGU	49.00%	Uruguay	Pipeline maintenance	December 31
EGS (“in liquidation”)	49.00%	Argentina	Pipeline exploitation and construction	December 31
Link	49.00%	Argentina	Pipeline exploitation and construction	December 31

4.b.3) Joint arrangement

As indicated in “Note 23 – Associates and Joint Arrangement”, on August 7, 2017, the Company proceeded to create a UT (similar to a joint operation) with SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A. (“SACDE”) (“UT”). This operation is evaluated as a joint agreement under the provisions included in “IFRS 11 - Joint Arrangements” since the parties have joint control of the operation, meaning that the decisions of the relevant activities are taken under the unanimous consent of the parties.

The Company has defined that the UT constitutes a joint operation given that it grants its participants a percentage of the rights over the assets and liabilities arising from each contract. Accordingly, the Company recognizes its share in the jointly operated assets, liabilities, revenues, costs and expenses.

Accounting policies applicable to the UT have been modified and adapted, if applicable, to ensure consistency with the policies adopted by the Company. For further information regarding the UT, see Note 23.

Foreign currency translation

4.c) 
Foreign currency translation

4.c.1) Functional and presentation currency

The consolidated financial statements are presented in thousands of Argentine Pesos, which is the Company’s functional currency. Each subsidiary or associate determines its own functional currency based on the currency of the primary economic environment in which these entities operate.

4.c.2) Transactions and balances

Foreign currency transactions are translated into the functional currency using the exchange rate prevailing at the dates of the transactions or valuation where items are remeasured. Foreign exchange gains and losses resulting from the settlement of such transactions and from the translation at year-end exchange rates of monetary assets and liabilities denominated in foreign currencies are recognized in the profit or loss for the year.

Foreign exchange gains and losses are presented in the statement of comprehensive income within financial income and financial expenses, as appropriate.

4.c.3) Associates

The functional currency of the associate company TGU, which is located abroad, is the US dollar, because it is the currency in which it substantially generates its income and incurs its expenses. Assets and liabilities were converted into Argentine pesos using the exchange rate prevailing at the end of each year, their common stock and retained earnings at their historical exchange rates and results at average exchange rates.

Restatement to constant currency - Comparative Information

4.d) Restatement to constant currency - Comparative Information

4.d.1) Regulatory framework

The consolidated financial statements as of December 31, 2022, including comparative figures, have been restated to take into account changes in the general purchasing power of the Company’s functional currency (the Argentine peso) in accordance with IAS 29 “Financial Reporting in hyperinflationary economies” (“IAS 29”) and CNV General Resolution No. 777/2018. As a result, the financial statements are stated in terms of the current unit of measurement at the 2022 balance sheet date.

IAS 29 requires that the financial statements of an entity that reports in the currency of a hyperinflationary economy, regardless of whether they are based on the historical cost method or the current cost method, are expressed in terms of the current unit of measurement at the closing date of the reporting period. In order to conclude on the existence of a hyperinflationary economy, the standard details a series of factors to be considered, among which is a cumulative inflation rate over three years that approaches or exceeds 100%.

The accumulated inflation in three years is over 100%. Likewise, both the National Government projections and other available projections indicate that this trend will not be reversed in the short term.

To evaluate the aforementioned quantitative condition, and also to restate the financial statements, the CNV has established that the series of indexes to be used for the application of IAS 29 is determined by the FACPCE. This series of indexes combines the National Consumer Price Index (“CPI”) as of January 2017 (base month: December 2016) with the Domestic Wholesale Price Index (“IPIM”), both published by the Institute National Statistics and Census (“INDEC”) until that date. For the months of November and December 2015, for which there is no information from the INDEC on the evolution of the IPIM, the variation in the CPI of the Autonomous City of Buenos Aires was applied.

Considering the aforementioned index, inflation was 94.79%, 50.94% and 36.14% in the years ended December 31, 2022, 2021 and 2020 respectively.

4.d.2) Restatement mechanism

The financial statements must be adjusted to consider changes in the general purchasing power of the currency, so that they are expressed in the current unit of measurement at the end of the reporting period. Said requirements also include all the comparative information of the financial statements, without modifying the decisions made based on the financial information corresponding to those financial years.

The figures as of December 31, 2021 and 2020, which are presented in these Consolidated Financial Statements for comparative purposes, arise from the restatement to the current unit of measure of the Financial Statements as of said dates, in accordance with IAS 29.

Restatement of the balance sheet

i. Monetary items (those with a fixed nominal value in local currency) are not restated, since they are already expressed in the current unit of measurement at the closing date of the reporting period. In an inflationary period, maintaining monetary assets generates loss of purchasing power and maintaining monetary liabilities generates a gain in purchasing power, provided that such items are not subject to an adjustment mechanism that compensates to some extent for these effects. The monetary loss or gain is included in the result of the period in which it is reported.

ii. The non-monetary items measured at their current values at the end of the reporting period are not restated for the purpose of their presentation in the balance sheet, but the adjustment process must be completed to determine in terms of a homogeneous unit of measurement the results produced by the holding of these non-monetary items.

iii. Non-monetary items measured at historical cost or at a fair value as of a date prior to the closing date of the reporting period are restated by coefficients that reflect the variation in the general price level from the date of acquisition or revaluation to the closing date, proceeding then to compare the restated amounts of those assets with the corresponding recoverable values.

iv. The restatement of non-monetary assets in the terms of the current unit of measurement at the end of the reporting period without an equivalent adjustment for tax purposes, results in a temporary taxable difference and the recognition of a deferred tax liability whose counterparty is recognized in the result of the period. For the closing of the subsequent period, the deferred tax items are restated for inflation to re-determine the charge to the result of the next period.

v. When the capitalization of costs for loans in non-monetary assets in accordance with IAS 23 is applicable, the portion of those costs that compensate the lender for the effects of inflation is not capitalized.

Restatement of the Comprehensive Income Statement

Revenues and expenses (including interest and foreign exchange differences) are restated from the date of their booking, except for those items of the result that reflect or include in their determination the consumption of assets measured in purchasing power of a date before the consumption booked, which are restated based on the date of origin of the asset to which the item is related (for example, depreciation and other consumption of assets valued at historical cost); and also those results that arise from comparing two measurements expressed in purchasing power currency of different dates, for which it is necessary to identify the amounts compared, restate them separately, and make the comparison, but with the amounts already restated.

The result of the exposure to the change in the purchasing power of the currency (monetary results) is presented in a separate line and reflects the effect of inflation on the monetary items.

Restatement of the statement of changes in equity

As of the transition date (January 1, 2016), the Company applied the following special rules:

i. The components of the capital stock were restated from the dates they were contributed.

ii. Reserved earnings were maintained at the date of transition at their nominal value (legal amount without restatement).

iii. The restated unallocated results were determined by the difference between the net assets restated at the transition date and the rest of the initial equity components expressed as indicated in the preceding sections.

iv. After the restatement at the transition date, all the components of the equity are restated by applying the general price index from the beginning of the period, and each variation of those components is restated from the date of contribution or from the moment in which is added by any other means.

Restatement of the statement of cash flows

IAS 29 requires that all items in this statement should be restated in terms of the current unit of measurement as of the closing date of the period for which it is reported.

The monetary result generated by cash and cash equivalents is presented in the Statement of Cash Flows separately from cash flows from operating, investing and financing activities, as a specific item of the reconciliation between cash and cash equivalents at the beginning and at the end of the year.

Financial instruments

4.e) Financial instruments

4.e.1) Financial assets

Recognition and initial measurement

Financial assets are classified, at the time of initial recognition, as:

• Financial assets subsequently measured at amortised cost, and

• Financial assets subsequently measured at fair value (either with changes in other comprehensive income or with changes in results).

The classification of financial assets at initial recognition depends on the financial asset’s contractual cash flow characteristics and the Company’s business model for managing them. For additional information, see Note 16.2.1.

Subsequent measurement

After initial recognition, financial assets are measured according to their initial classification according to the following categories:

Financial assets measured at amortised cost

It is the most relevant category used by the Company, financial assets are classified and measure at amortised cost if both of the following conditions are met:

• The financial asset is held within a business model with the objective to hold financial assets in order to collect contractual cash flows; and

• The contractual terms of the financial asset give rise on specified dates to cash flows that are solely payments of principal and interest on the principal amount outstanding.

Financial assets measured at amortised cost are subsequently measured using the effective interest method.

Gains and losses are recognized in the Statement of Comprehensive Income under financial results when the asset is derecognized, modified or impaired.

Financial assets at fair value through OCI (Debt instruments)

Corresponds to financial assets that are maintained in a business model whose objective is achieved by obtaining contractual cash flows and selling them.

Unrealized gains or losses arising from changes in fair value are recognized as other comprehensive income, except for the accrual of interest, exchange rate difference and the impairment of such assets that are recognized as financial results in the Statement of Comprehensive Income. At the time the asset is written off, the accumulated gain or loss is recognized as a financial result and it is eliminated from the respective reserve.

As of December 31, 2022 and 2021, the Company has not recognized any financial assets under this category.

Financial assets designated at fair value through OCI (equity instruments)

Upon initial recognition, the Company can elect to classify irrevocably its equity investments as equity instruments designated at fair value through OCI when they meet the definition of equity under IAS 32.

Gains and losses on these financial assets are never recycled to profit or loss. Dividends are recognized as other income in the Statement of Comprehensive Income when the right of payment has been established, except when the Company benefits from such proceeds as a recovery of part of the cost of the financial asset, in which case, such gains are recorded in OCI. Equity instruments designated at fair value through OCI are not subject to impairment assessment.

As of December 31, 2022 and 2021, the Company has not recognized any financial assets under this category.

Financial assets at fair value through profit or loss

In the event that financial assets are not classified according to the aforementioned categories, they will be subsequently measured at fair value, presenting gains or losses arising from changes in fair value in the income statement within financial results in the year in which they are originated.

Impairment of financial assets

The Company applies the Expected Credit loss (“ECL”) model for those financial assets accounted for at amortised cost or at fair value through OCI. The ECL is based on the difference between the contractual cash flows due in accordance with the contract and the cash flows that the Company expects to receive, discounted at an approximation of the original effective interest rate. To this end, the Company evaluates various factors, including credit risk, historical trends and other available information.

The application of this model implies recognition of:

• Expected credit losses within of 12 months: these are expected credit losses that result from possible default events within 12 months after the filing date; and

• Expected credit losses during the life of the asset: these are expected credit losses that result from possible events of default during the expected life of a financial instrument.

In case a loss allowance is recognized, the carrying amount of the asset is reduced through an impairment account and the amount of the loss is presented in the Statement of Comprehensive Income at the time it occurs. Subsequent recoveries of amounts previously written off are credited in the same line item.

The impairment tests performed on accounts receivable are described in Note 4.h.

4.e.2) Financial liabilities

Includes trade payables, loans, other payables and certain payroll and social security taxes payable.

Recognition and initial measurement

Financial liabilities are classified, at initial recognition, as subsequently measured at amortised cost or at fair value through profit or loss, as appropriate.

All financial liabilities are recognized initially at fair value net of transaction costs.

They are classified in current liabilities, except those whose maturity exceeds twelve months, which are classified as non-current liabilities.

Subsequent measurement

Financial liabilities at fair value through profit or loss

Includes financial liabilities measured at fair value. As of December 31, 2022 there are no instruments classified in this category. As of December 31, 2021 the Company includes derivative financial instruments under this category.

Financial liabilities at amortised cost

The Company includes financial liabilities with fixed or determinable payments that are not quoted in an active market. Current liabilities are included, except those whose maturity exceeds twelve months including premiums, discounts and direct expenses, which are included as non-current liabilities. They are measured using the effective interest method. As of December 31, 2022 and 2021, all of the Company’s financial liabilities were classified in this category.

Offsetting of financial instruments

Financial assets and liabilities are offset when there is a legally enforceable right to offset the recognized amounts and there is an intention to settle on a net basis, or realize the asset and settle the liability simultaneously.

Derivative financial instruments

4.f) Derivative financial instruments

Derivative financial instruments are recognized at their fair value at inception and subsequently measured at their fair value and disclosed as assets or liabilities depending if it is gain or loss. The results of derivative financial instruments are classified under “Financial income / expenses” in the statement of comprehensive income, or in the other comprehensive income if hedge accounting is applied.

Derivative financial instruments are measured in accordance with IFRS 13 “Fair value measurement”.

The method of recognizing the resulting gain or loss depends on whether the derivative is designated as a hedging instrument or not and, according to the nature of the item being hedged.

As of December 31, 2021, the Company had contracted forward operations for the purchase of US dollars, (which qualify as exchange-traded futures), which are disclosed in the item “Derivative financial instruments” of the Statement of Financial Position, for which the application of the hedge accounting as defined by IFRS 9 has not been elected. The (loss) / gain for the year was included in the line “Derivative financial instruments result” in “Financial Results” in the Statement of Comprehensive Income. For more information, see notes 16.1.1 and 16.1.3 to these financial statements.

Inventories

4.g) Inventories

Inventories consist of natural gas (in excess of the “Line Pack”, classified as property, plant and equipment) in the Company’s pipeline system, and the liquids stored obtained from natural gas processing at the Cerri Complex.

Inventories are measured at the lower of cost restated for the inflation effects as mentioned in Note 4.d. or net realizable value. Cost is determined using the weighted average cost method. The cost of inventories includes expenditure incurred in purchasing and production and other necessary costs to bring them to their existing location and condition.

The net realizable value is the estimated selling price in the ordinary course of business less the estimated cost of completion and the estimated costs to make the sale.

The assessment of the recoverable value of these assets is made at each reporting date, and the resulting loss is recognized in the statement of comprehensive income when the inventories are overstated.

Trade receivables and other receivables

4.h) Trade receivables and other receivables

Trade receivables are amounts due from customers for goods and services performed in the ordinary course of business. Contract assets are unbilled amounts due to customers related to works in progress.

Trade receivables, contract assets and other receivables are recognized initially at fair value and subsequently measured at amortised cost using the effective interest method, less allowance for trade receivables.

The Company applies the simplified approach to measuring expected credit losses for trade receivables, contract assets and other receivables. For this purpose, customers have been grouped based on shared credit risk characteristics, the existence of guarantees, historical credit losses experienced and the existence of judicial proceedings aimed at obtaining payment. Once each group was defined, an expected uncollectibility rate calculated based on historic default rates adjusted to future economic conditions was defined.

Impairment losses on trade receivables and contract assets are presented as net impairment losses within operating profit. Subsequent recoveries of amounts previously written off are credited against the same line item.

Cash and cash equivalents

4.i) Cash and cash equivalents

Cash and cash equivalents includes cash in hand, deposits with banking institutions and other short-term, highly liquid investments with original maturities not exceeding three months and without being subject to a risk of a significant change of value.

Property, plant and equipment ("PPE")

4.j) Property, plant and equipment (“PPE”)

Assets transferred from the privatization of GdE: The value of these assets was determined based on the price paid for the acquisition of 70% of the Company’s common stock, which amounted to U.S.$ 561.2 million. This price was the basis to determine a total value of common stock of U.S.$ 801.7 million, which, when added to the debt assumed under the Company’s privatization agreement (the “Transfer Agreement”) of U.S.$ 395.0 million, resulted in a total value for PPE of U.S.$ 1,196.7 million. Such value, converted at the exchange rate in effect as of the date of the Transfer Agreement, has been restated for the effects of inflation as mentioned in Note 4.d, and less accumulated depreciation.

Line pack: It represents the natural gas in the transportation system that is necessary to keep the system at operating capacity, valued at acquisition cost and restated for the effects of inflation as mentioned in Note 4.d.

Materials: Materials are recognized at historical cost restated in accordance with Note 4.d. Consumption is restated based on the origin date of the acquisition of the asset.

Other items of PPE: have been valued at acquisition cost restated for the effects of inflation as mentioned in Note 4.d, and net of accumulated depreciation. They include, mainly, all the investments made to achieve system integrity and public safety equal to those required by international standards. Such investments included, among others, the costs of survey programs related to internal and external pipeline inspection, cathodic protection, pipeline replacement and recoating, and the facilities affected to the Production and Commercialization of Liquids and Other Services segment.

PPE additions are recorded at acquisition or construction cost less accumulated depreciation and impairment losses (if applicable), except land, which is recorded at historical cost acquisition minus any impairment (if applicable), all this restated for the effects of inflation as mentioned in Note 4.d. The cost includes the cost of replacing significant components and the borrowing costs derived from loans that finance its construction to the extent that the requirements for recognition as assets are met.

Subsequent costs restated for the effects of inflation as mentioned in Note 4.d. are included in the carrying amount of the asset or recognized as a separate asset, as appropriate, only when it is probable that future economic benefits associated with the item will flow to the Company and the cost of the item can be reliably measured. The carrying amount of a replaced component is written off. In the same way, when a major maintenance is carried out, they are added to the cost of the equipment if the recognition criteria are satisfied, eliminating any remaining non-depreciated remaining value restated for the effects of inflation as mentioned in Note 4.d, if any, of previous overhaul.

In this sense, Resolutions No. 1660/2000 (“Resolution 1660”) and No. 1903/2000 (“Resolution 1903”) issued by ENARGAS include definitions about the costs that should be considered as improvements or maintenance expenses. All other repairs and maintenance are charged to the statement of comprehensive income when incurred.

In accordance with IAS 23, the Company capitalizes financial expense on long term construction projects, until the moment in which the asset is in conditions for its use. Capitalization of borrowing costs is carried out considering the provisions of IAS 29, recording as an expense in the Statement of Comprehensive Income the part of the borrowing costs that compensates for inflation during the same period. As of December 31, 2022 and 2021 there have not been capitalized borrowing costs.

Depreciation related to natural gas transportation assets is computed under the straight -line method over the estimated useful lives of the specific assets, which are not exceeding the maximum useful lives established by ENARGAS through Resolutions 1660 and 1903.

For depreciation of all other PPE, the Company uses the straight-line method of depreciation based on the useful life assigned to each item.

Major maintenance costs are depreciated according to the estimated time until the next major maintenance planned. Regarding the capitalized financial costs, they are depreciated based on the remaining useful lives of those components of PPE that originated such capitalization.

The assets’ residual values and useful lives are reviewed, and adjusted if appropriate, at each reporting date. For further information, see Note 12.

The result generated by the disposal of PPE components is recognized in the year in which it is generated.

Impairment of non-financial assets: The Company assesses at each reporting period whether there is an indication that an individual component or a group of PPE may be impaired.

If any indication exists, the Company estimates the asset´s recoverable amount. An asset´s recoverable amount is the higher of the fair value less costs to sell that asset, and its value-in-use.

That amount is determined for and individual asset, unless the asset does not generate cash inflows that are largely independent of those from other assets or groups of assets; in which case, the cash flows of the group of assets that form part of the cash-generating unit (“CGU”) to which the belong are taken.

Where the carrying amount of an individual asset or CGU exceeds its recoverable amount, the individual asset or CGU, as the case may be, is considered impaired and is written down to its recoverable amount. Impairment losses are recognized in the consolidated statement of comprehensive income.

In assessing value in use, the estimated future cash flows are discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset for which the estimates of future cash flows have not been adjusted. To such end, the management makes estimates and assumptions of the economic conditions that will prevail throughout the useful life of the assets.

As a result of the factors mentioned above, actual cash flows and values could vary significantly from projected cash flows and the values derived from the discounting techniques used.

Impairment losses, if any, are recognized in the statement of comprehensive income.

As of December 31, 2022 and 2021, the book value of PPE did not exceed its recoverable value.

Infrastructure used in the natural gas transportation service: for its measurement and disclosure, the Company has evaluated the application of Interpretation No. 12 “Service Concession Agreements” (IFRIC 12) that sets the guidelines for the accounting of private entities that provide public services through a service concession agreement or a contract of a similar nature.

Considering the current terms and conditions of the License, tgs concluded that the License is outside the scope of IFRIC 12, as it is considered in substance to provide for an indefinite term because the infrastructure will never revert to the grantor and due to the characteristics of renewal of the License that give a similar result to what which would result from having obtained a perpetual right to operate the infrastructure.

The evaluation carried out and the conclusions reached by tgs are consistent with those of other transportation and natural gas distribution companies in Argentina that are subject to the similar regulations and license agreements. The evaluation was carried out jointly, when the transportation and distribution companies adopted the IFRS in Argentina in 2012, together with the FACPCE, the Buenos Aires Stock Exchange (Bolsas y Mercados Argentinos -“BYMA”) and the CNV, considering the contributions of ENARGAS with respect to the regulatory aspects of the License agreements. In this regard, the CNV issued General Resolution No. 613/2012, ratifying that IFRIC 12 does not apply to natural gas transportation and distribution licenses established under the regulatory framework described in Note 17.

Leases

4.k) Leases

Leases are recognized as a right-of-use asset and a corresponding liability at the date on which the leased asset is available for use by the Company. Each lease payment is allocated between the liability and the finance cost. The finance cost is expensed over the lease term to produce a constant periodic interest rate on the remaining balance of the liability for each period. The right-of-use asset is depreciated over the shorter of the useful life of the asset or the term of the contract.

Assets and liabilities arising from a lease are initially measured based on the present value of the lease. Liabilities include the net present value of the following lease payments:

a) Fixed payments, less any incentive receivable;

b) Variable lease payments;

c) Amounts expected to be collected as a guarantee of the residual value;

d) The exercise price of the lease option; and

e) Penalty payments for termination of the lease.

Lease payments are discounted using the interest rate implicit in the lease. If such rate cannot be determined, the Company’s incremental borrowing rate is used, which is the rate that tgs would have to pay to borrow the funds necessary to obtain an asset of similar value in a similar economic environment.

Right-of-use assets are measured at cost which comprises the following:

a) The amount of the initial measurement of the lease liability;

b) Any lease payments made on or before the commencement date less any lease incentives received;

c) Any initial direct costs; and

d) Restoration costs

These assets, which are subject to the risk of impairment, are depreciated on a straight-line basis over the shorter of the useful life of the leased asset or the lease term.

Payments associated with short-term leases and low-value assets are recognized on a straight-line basis as an expense in the Statement of Income. Short-term leases are those with a term of 12 months or less. Low-value assets comprise computer equipment, vehicles, small items of office furniture and real estate.

The Company has rights to use assets that are shown as part of Property, plant and equipment (see Note 12). Lease liabilities are shown under Financial Debt (see Note 13). For further information regarding the expense related to short-term and low value leases and the interest expense on lease liabilities, see Note 8.j. and 8.k., respectively.

Loans

4.l) Loans

Loans have been initially recorded at fair value net of direct attributable transaction costs. Subsequently, loans are valued at their amortised cost. Liabilities are disclosed as non-current when their maturity exceeds twelve months.

Trade payables

4.m) 
Trade payables

Trade payable are initially recognized at fair value. Subsequently they are measured at amortised cost using the effective tax method.

Income tax and deferred income tax

4.n) Income tax and deferred income tax

Income tax includes current tax and deferred income tax. Income tax is presented in the Statement of Comprehensive Income.

The current income tax is calculated on the basis of tax regulations in force at each reporting period. Management periodically evaluates positions taken in tax returns with respect to situations in which tax regulations are subject to interpretation and establishes provisions if applicable. As of December 31, 2022 and 2021, there are no provisions booked for this concept.

The Company has calculated income tax charges using the deferred tax method, which considers the effect of temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases.

Deferred income tax assets and liabilities are measured at undiscounted nominal value at the tax rates that are expected to apply in the year when the asset is realized or the liability is settled, based on tax rates and tax laws that have been enacted or substantively enacted at the reporting period rate (See Note 14).

A deferred tax is recognized on the temporary differences arising from investments in subsidiaries and associates, except for deferred tax liabilities where the Company is able to control the timing of the reversal of the temporary difference and it is probable that the reversal will not occur in the foreseeable future.

Deferred tax assets and liabilities are offset if the Company has a legally enforceable right to offset recognized amounts and when deferred tax assets and liabilities relate to income tax levied by the same tax authority on the same taxable entity or different taxable entities that intend to settle tax assets and liabilities on a net basis. Deferred tax assets are recognized to the extent that it is probable that future taxable income will be generated against which the temporary differences can be used.

The assets and liabilities generated by the application of the deferred tax were valued at their nominal amount considering the restatements for inflation mentioned in Note 4.d) and are classified as non-current assets or liabilities.

Provisions

4.o) Provisions

The Company has recorded provisions related to legal actions, judicial court, claims and administrative proceedings, including interpretive questions of the current legislation and those of regulatory nature.

Provisions for legal claims and/or claims by third parties (“legal claims and others”) are recorded at the expected cancellation value when the Company has a present obligation as a result of a past event, it is probable that an outflow of resources will be required to settle the obligation; and the amount has been reliably estimated. Estimates are reviewed and adjusted, as the Company obtains additional information to be received.

Revenue recognition from contract with customers

4.p) Revenue recognition from contract with customers

Revenue is measured at the fair value of the consideration received or to be received, and represents amounts receivable for goods and/or services supplied. Revenue is recognized when the control of goods or services is transferred to the customer and the consideration is determined by an amount that reflects the consideration that the Company expects to receive.

Tax on exports and turnover tax are disclosed as Selling Expenses.

The following are the accounting policies of the Company for the recognition of revenue of each of the business segments defined by our management:

Natural Gas Transportation

Natural Gas transportation services includes: (i) firm natural gas transportation, whose revenues are recognized when the capacity is reserved and paid for regardless of actual usage by the customer, (ii) interruptible natural gas transportation and exchange and displacement services whose revenues are recognized when services are rendered and (iii) the operation and maintenance service of the assets affected by the natural gas transportation service corresponding to the expansions promoted by the National Government and whose ownership corresponds to the trusts created for such purpose whose revenues are recognized when services are rendered.

The applicable rates arise from the tariff tables published by ENARGAS. Thus Company’s revenues are recognized by the amount for which it will be entitled to receive as consideration.

At the end of each month, tgs recognizes, over the time, its revenues from sales equivalent to the firm reserved capacity, the volumes of natural gas transported under the modalities of interruptible and exchange and displacement and by the operation and maintenance services. In return, a trade receivable is recognized which represents an unconditional right that the Company has to receive the consideration owed by the customer. On the other hand, the billing of the service is done monthly and according to the guidelines established by ENARGAS, the consideration is received within said calendar month.

Liquids Production and Commercialization

This business segment includes: (i) production and commercialization of liquids on our own account which revenues are recognized in a point in time, and (ii) other liquid services which revenues are recognized over the time.

Liquids Production and Commercialization in the domestic market

In the domestic market, tgs sells the production of propane and butane to LPG retailers in the framework of the programs created by the National Government to supply the domestic market. The sale prices are determined by the ex-Secretary of Hydrocarbon Resources (“SHR”). For more information, see Note 17 - Regulatory framework – b) Regulatory framework for non-regulated segments - to these consolidated financial statements.

The price of those tons of propane and butane that are not sold within the framework of the aforementioned programs is determined by the ex-Ministry of Energy and Mining (“ex MINEM”) based on the international reference prices.

Regarding ethane sales, they are made to PBB Polisur S.R.L. (“PBB”), the only customer to whom this product is sold. To estimate transaction price, the Company uses the most probable amount method. In this regard, the Company only recognizes those transactions where it is highly probable that they will not be reversed in the future.

Liquids Production and Commercialization in the foreign market

In the foreign market, the Company markets propane, butane and natural gasoline to international traders (“traders”) and other clients of worldwide renown, some of them through trucks.

These sales are made under short-term contracts (less than one year), with the price determined as reference to international prices plus / minus a fixed amount per ton sold. There are no variable consideration components in these contracts.

For both domestic and foreign market sales, tgs transfers control and recognizes revenues when the products are delivered to the customer and therefore the product has been accepted and there is no evidence of the existence of pending obligations by the Company. It is at that moment when a trade receivable is recognized given that the receipt of the consideration is unconditional and only the passage of time is the only requirement for receiving the consideration owed by the customer.

Other liquids services

The Liquids production and commercialization segment also comprises reception, storage and dispatch of the liquids from the facilities located in Puerto Galván.

Revenues from sales are recognized when the service is effectively rendered, that is, after the dispatch to each vessel. The price is agreed by the parties being a fixed amount per ton of product dispatched, there being no variable components in them.

These services are billed monthly, at which time an unconditional right to receive the consideration from the client arises.

Subsidies

As part of its participation in propane and butane supply programs in the local market carried out by the National Government, (for more information see “Note 17 - Regulatory Framework - b) Regulatory framework for non-regulated segments”), the Company receives from the Secretary of Energy a series of subsidies that are recognized in accordance with the provisions of IAS 20 “Accounting for government grants and disclosures of government assistance” because they correspond to economic compensations calculated as the difference between the sale prices of the products determined in accordance with the legislation in force and the reference prices calculated by the Secretary of Energy.

Subsidies are recognized at fair value whenever there is reasonable assurance that will be received and that the product has been delivered. They are presented within the caption “Revenues” of the statement of comprehensive income.

Other services

The services included in the Other Services segment consist mainly in (i) treatment, removal of impurities and natural gas compression, including the collection and transport of natural gas (ii) inspection and maintenance of pipelines and compressor plants, (iii) services of steam generation for electricity production and management services for expansion works and steam generation for the production of electricity and (iv) natural gas transportation services in Vaca Muerta.

Revenues from sales of this business segment are recognized over the time in the period in which the service is provided. The sale price is determined according to what arises from the contractual conditions agreed between tgs and its customers. In all cases, the recognition and billing of sales income is made on a monthly basis so that at that time a sales credit is recorded.

Revenues from the participation in the joint venture, which correspond to the construction activities provided by the joint venture, are recognized based on the stage of completion of the contractual activity (percentage of completion method), considering the estimated final margin of the work. To apply the percentage of completion method, the revenue recognized at the end of the period will correspond to the total contractual revenue multiplied by the actual percentage of completion, based on the proportion of the total direct contractual costs incurred to date, and the total direct contractual costs, including the estimated costs to complete the construction. Costs incurred in excess of the costs associated with revenue are recognized in Contract assets.

Telecommunications

Revenues from the provision of Telecommunications services are recognized in the statement of comprehensive income at the time of effective performance of the service. The sale price is determined according to what arises from the contractual conditions agreed between tgs and its customers. The consideration is determined as a fixed monthly amount. In all cases, the recognition and billing of sales income is made on a monthly basis so that at that time a sales receivable is recorded.

Financial components

The Company does not have any contracts where the period between the transfer of the promised goods or services to the customer and payment by the customer exceeds one year. As a consequence, the Company does not adjust any of the transaction prices for the time value of money.

Contract liabilities

4.q) Contract liabilities

Mainly consist of pre-payments for services made by customers in order to finance the works to render the service. Contract liabilities are recognized initially at their fair value. Subsequent to initial recognition, advances from customers are measured at their amortised cost based on the projections of the services to be provided that cancel the advances, restated for the inflation effects as mentioned in Note 4.d).

Additionally, it includes the advance received by the UT from the Argentine Government as payment on account of the gas pipeline construction project. For more information, see “Note 23 - Associates and joint arrangements.”

Equity accounts

4.r) Equity accounts

The activity in the Equity accounts reflects resolutions adopted by Shareholders in their meetings, or the effects of the laws or regulations in force. The equity accounts are restated for the inflation effects according to what is mentioned in Note 4.d), except the account Capital stock which is maintained at its original value.

Common stock and adjustment to common stock

The common stock consists of contributions made by shareholders represented by shares and comprises outstanding shares at their face value, net of treasury shares mentioned below.

Common stock accounts were restated in constant currency as mentioned in Note 4.d). Common stock account was kept at original value and the adjustment arising from such restatement is shown under “Inflation Adjustment to common stock”.

Common stock adjustment is not distributable in cash or in kind but may be capitalized through issuance of shares. In addition, this balance may be used to compensate accumulated losses.

Treasury shares and adjustments to treasury shares

Corresponds to the reclassification of the nominal value and corresponding restatement in constant peso (Inflation Adjustment to Common Stock) of shares issued and repurchased by the Company in market transactions, as required by the current regulations of the CNV.

Own equity instruments that are reacquired (treasury shares) are recognized at cost restated for the inflation effects as mentioned in Note 4.d), and deducted from equity. No gain or loss is recognized on the purchase, sale or cancellation of the Company’s treasury shares. Any difference between the carrying amount and the consideration, if reissued, is recognized as a premium on common stock or additional paid-up capital.

Additional paid-up capital

Corresponds to the difference between the carrying value of the treasury shares and the quoted value at the time were distributed (for more information see Note 19.b). It is restated according to what is mentioned in Note 4.d).

Legal Reserve

Pursuant to the provisions of the Argentine Business Association Law and the CNV, the Company is required to set up a legal reserve by providing at least 5% of the aggregate amount of net income for the year, prior year adjustments, transfers of other comprehensive income to retained earnings and accumulated losses of prior years, when this aggregate amount exceeds zero until the legal reserve equals 20% of the sum of Capital stock and Adjustment to capital stock balances.

Distribution of dividends

The cash dividend is recognized as a liability in the Company’s financial statements in the year in which they are approved by the shareholders of the Company or the Board of Directors according to the powers delegated by the Shareholders’ Meeting, as appropriate.

Retained earnings

The outstanding balance of retained earnings includes accumulated gains or losses which were not allocated to a specific purpose reserve and, when positive, may be distributed pursuant to the decision of the Shareholders provided these retained earnings are not subject to legal restrictions, as mentioned above “Legal reserve”.

Basic and diluted earnings per share

4.s) Basic and diluted earnings per share

Earnings per share as of December 31, 2022, 2021 and 2020 were calculated as follows:

	2022		2021		2020
Net income attributable to owners of the Company		32,317,790		40,772,306		9,662,187
Average number of outstanding shares (1)		752,761,058		752,761,058		762,371,755
Basic and diluited earnings per share		42.93		54.16		12.68

⁽¹⁾ The weighted average number of shares considers the effect of the weighted average of the changes originated in the transactions with the treasury shares made during the year.

As of December 31, 2022, 2021 and 2020, there are no tgs instruments outstanding that imply the existence of potential ordinary shares, thus the basic net income per share for each of the three years ended on December 31, 2022, 2021 and 2020 matches the diluted net income per share.

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BUSINESS DESCRIPTION (Tables)

12 Months Ended

Dec. 31, 2022

BUSINESS DESCRIPTION [Abstract]

Organizational Structure, Shareholders and Related Parties

The following table shows the organizational structure, shareholders and related parties of tgs as of December 31, 2022:

44%, 24%, 8%, 12%, 5%, 51%, 49%, 51%, 49%, 99.98%, 0.02%, 80%, 15%, 5%, 100%, 49%, 25.5%, 20.4%, 5.1%

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SIGNIFICANT ACCOUNTING POLICIES (Tables)

12 Months Ended

Dec. 31, 2022

SIGNIFICANT ACCOUNTING POLICIES [Abstract]

Subsidiary Control

Detailed data reflecting subsidiary control as of December 31, 2022 and 2021 is as follows:

		% of shareholding and voting
Company	Incorporation country	Direct			Indirect			Closing date	Main activity
Telcosur	Argentina		99.98	%		-		December 31	Telecommunication Services
CTG	Argentina		100	%		-		December 31	Electricity related services
TGSLatam	Bolivia		80	%		100	%	December 31	Hydrocarbons and Electrical power related services

Associates

In the table below, associates are disclosed, together with the percentage of shareholding and voting as of December 31, 2022 and 2021:

Company	% of shareholding and voting	Country	Main activity	Closing date
TGU	49.00%	Uruguay	Pipeline maintenance	December 31
EGS (“in liquidation”)	49.00%	Argentina	Pipeline exploitation and construction	December 31
Link	49.00%	Argentina	Pipeline exploitation and construction	December 31

Earnings Per Share

Earnings per share as of December 31, 2022, 2021 and 2020 were calculated as follows:

	2022		2021		2020
Net income attributable to owners of the Company		32,317,790		40,772,306		9,662,187
Average number of outstanding shares (1)		752,761,058		752,761,058		762,371,755
Basic and diluited earnings per share		42.93		54.16		12.68

⁽¹⁾ The weighted average number of shares considers the effect of the weighted average of the changes originated in the transactions with the treasury shares made during the year.

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SUPPLEMENTAL CASH FLOW INFORMATION (Tables)

12 Months Ended

Dec. 31, 2022

SUPPLEMENTAL CASH FLOW INFORMATION [Abstract]

Supplemental Cash Flow Information

Non-cash investing and financing activities for the years ended December 31, 2022, 2021 and 2020 are presented below:

	2022		2021		2020
Unpaid acquisition of PPE		1,846,947		1,856,040		895,394
Principal payment of financial lease (1)		901,526		1,163,922		561,495

⁽¹⁾ Cancelled through compensation with trade receivables with the creditor. See Note 13.

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CONSOLIDATED BUSINESS SEGMENT INFORMATION (Tables)

12 Months Ended

Dec. 31, 2022

CONSOLIDATED BUSINESS SEGMENT INFORMATION [Abstract]

Business Segments

Detailed information on each business segment for the years ended December 31, 2022, 2021 and 2020 is disclosed below:

Year ended December 31, 2022
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenues from sales		40,643,462			104,214,859			18,747,054			919,414			-			164,524,789
Intersegment revenues		1,164,760			-			-			-			(1,164,760	)		-
Cost of sales		(29,357,094	)		(58,784,800	)		(8,407,580	)		(656,850	)		1,164,760			(96,041,564	)
Administrative expenses		(4,230,811	)		(829,258	)		(627,243	)		(67,121	)		-			(5,754,433	)
Selling expenses		(3,019,249	)		(5,737,983	)		(1,336,806	)		(109,559	)		-			(10,203,597	)
Other operating results		(180,352	)		37,940			65,914			-			-			(76,498	)
Operating profit		5,020,716			38,900,758			8,441,339			85,884			-			52,448,697
Depreciation of property, plant and equipment		(14,385,464	)		(1,308,511	)		(3,878,694	)		-			-			(19,572,669	)

	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		224,390,925		79,765,071		102,867,810		5,068,419		412,092,225
Identifiable liabilities		68,642,296		7,941,685		63,768,842		4,515,113		144,867,936

Year ended December 31, 2021
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenue from sales		47,729,944			108,559,750			16,137,635			892,492			-			173,319,821
Intersegment revenues		1,753,852			-			-			-			(1,753,852	)		-
Cost of sales		(30,398,565	)		(56,280,587	)		(7,294,631	)		(623,473	)		1,753,852			(92,843,404	)
Administrative expenses		(3,820,247	)		(664,124	)		(465,910	)		(45,786	)		-			(4,996,067	)
Selling expenses		(3,353,756	)		(4,889,198	)		(1,010,116	)		(86,494	)		-			(9,339,564	)
Other operating results		(396,796	)		626,862			20,099			760			-			250,925
Operating profit		11,514,432			47,352,703			7,387,077			137,499			-			66,391,711
Depreciation of property, plant and equipment		(13,844,172	)		(1,194,842	)		(3,682,135	)		-			-			(18,721,149	)

			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		242,560,322		74,892,859		87,327,237		739,498		405,519,916
Identifiable liabilities		78,050,198		21,404,091		70,954,650		204,490		170,613,429

Year ended December 31, 2020
				Production and
	Natural Gas			Commercialization of			Other
	Transportation			Liquids			Services			Telecommunications			Eliminations			Total
Revenue from sales		69,100,376			81,140,913			12,832,687			1,201,467			-			164,275,443
Intersegment revenues		2,483,327			-			-			-			(2,483,327	)		-
Cost of sales		(29,218,827	)		(46,554,104	)		(6,938,313	)		(821,874	)		2,483,327			(81,049,791	)
Administrative expenses		(3,652,010	)		(746,192	)		(512,372	)		(37,239	)		-			(4,947,813	)
Selling expenses		(4,290,739	)		(3,457,748	)		(881,361	)		(96,031	)		-			(8,725,879	)
Other operating (expenses) / income		(129,779	)		411,530			7,383			4,388			-			293,522
Impairment of PPE		(9,156,072	)		-			-			-			-			(9,156,072	)
Operating profit		25,136,276			30,794,399			4,508,024			250,711			-			60,689,410
Depreciation of property, plant and equipment		(13,415,586	)		(1,125,453	)		(3,574,463	)		-			-			(18,115,502	)

			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Identifiable assets		243,316,895		52,023,450		82,037,118		720,848		378,098,311
Identifiable liabilities		81,196,369		15,989,754		86,567,711		210,291		183,964,125

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS (Tables)

12 Months Ended

Dec. 31, 2022

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS [Abstract]

Other Receivables

a) Other receivables

	2022				2021
	Current		Non Current		Current		Non Current
Turnover tax balance		220,927		-		246,803		-
Income tax credit balance		96,687		-		42,697		-
VAT credit balance		1,495,500		-		1,368,925		-
Other tax receivables		107,249		55		73,562		919
Prepaid expenses		1,524,421		-		814,670		-
Advances to suppliers		8,338,576		-		5,887,123		-
Subsidies receivables		3,768,159		-		2,427,450		-
Other Receivables UT		33,460		-		56,924		-
Others		591,659		14,844		724,109		16,330
Total		16,176,638		14,899		11,642,263		17,249

Trade Receivables

b) Trade receivables

	2022					2021
	Current			Non Current		Current			Non Current
Commons		15,741,345			-		20,256,312			-
UT		9,448			-		205,075			-
Natural Gas Transportation		4,398,150			-		6,681,903			-
Production and Commercialization of Liquids		8,189,884			-		10,793,068			-
Other services		3,143,863			-		2,576,266			-
Related parties (Note 21)		1,330,471			-		695,684			-
Natural Gas Transportation		131,145			-		158,708			-
Production and Commercialization of Liquids		281,774			-		210			-
Other services		917,552			-		536,766			-
Allowance for doubtful accounts		(132,521	)		-		(258,142	)		-
Total		16,939,295			-		20,693,854			-

The movement of the allowance for doubtful accounts is as follows:

Balances as of December 31, 2020	389,643
Inflation adjustment restatement	(131,501	)
Additions	-
Applications	-
Reversals	-
Balances as of December 31, 2021	258,142
Inflation adjustment restatement	(125,621	)
Additions	-
Applications	-
Reversals	-
Balances as of December 31, 2022	132,521

Cash and Cash Equivalents

c) Cash and cash equivalents

	2022		2021
Cash and banks		289,630		213,984
UT Cash and banks		159		142
Mutual funds in local currency		2,654,934		8,138,623
Interest-bearing accounts		33,343		214,906
UT Mutual funds		10,880		59,349
Total		2,988,946		8,627,004

Contract Liabilities

d) Contract liabilities

	2022				2021
	Current		Non Current		Current		Non Current
Natural Gas Transportation		360,887		5,902,032		360,886		6,262,944
Production and Commercialization of Liquids		345,243		557,671		263,596		902,915
Other services		326,802		5,257,709		327,971		3,797,298
UT		12,522		-		26,122		-
Total		1,045,454		11,717,412		978,575		10,963,157

Other Payables

e) Other payables

	2022				2021
	Current		Non Current		Current		Non Current
Payable for compensation for the Board of Directors and Supervisory Committee		68,039		-		37,809		-
Others		1,763		-		1,983		-
UT Other liabilities		216,753		-		580,178		-
Total		286,555		-		619,970		-

Taxes Payables

f) Taxes payables

	2022				2021
	Current		Non Current		Current		Non Current
Health and safety tax		52,339		-		41,921		-
Withholdings and perceptions made to third parties		581,800		-		621,114		-
Turnover Tax		158,382		-		267,965		-
Tax on exports		103,759		-		337,941		-
Others		48,416		14,285		28,485		-
Total		944,696		14,285		1,297,426		-

Trade Payables

g) Trade payables

	2022				2021
	Current		Non Current		Current		Non Current
Suppliers		9,717,662		-		10,662,184		-
UT Suppliers		119,077		-		129,333		-
Customers (credit balances)		15,237		-		18,778		-
Related companies (Note 21)		672,960		-		1,010,388		-
Total		10,524,936		-		11,820,683		-

Revenues

h) Revenues

	2022		2021		2020
Sales of goods and services		159,116,112		169,132,295		163,311,441
Subsidies		5,408,677		4,187,526		964,002
Total		164,524,789		173,319,821		164,275,443

Disaggregation of Revenues

Below is a table in which revenues are disaggregated considering the type of market and the opportunity to satisfy performance obligations:

Year ended December 31, 2022
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		46,313,662		-		-		46,313,662
Local market		40,643,462		57,901,197		18,747,054		919,414		118,211,127
Total		40,643,462		104,214,859		18,747,054		919,414		164,524,789
Timing of revenue recognition:
Over the time		40,643,462		4,504,128		18,747,054		919,414		64,814,058
At a point in time		-		99,710,731		-		-		99,710,731
Total		40,643,462		104,214,859		18,747,054		919,414		164,524,789

Year ended December 31, 2021
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		44,708,635		-		-		44,708,635
Local market		47,729,944		63,851,115		16,137,635		892,492		128,611,186
Total		47,729,944		108,559,750		16,137,635		892,492		173,319,821
Timing of revenue recognition:
Over the time		47,729,944		4,786,166		16,137,635		892,492		69,546,237
At a point in time		-		103,773,584		-		-		103,773,584
Total		47,729,944		108,559,750		16,137,635		892,492		173,319,821

Year ended December 31, 2020
			Production and
	Natural Gas		Commercialization of		Other
	Transportation		Liquids		Services		Telecommunications		Total
Primary geographical market:
External market		-		28,033,885		-		-		28,033,885
Local market		69,100,376		53,107,028		12,832,687		1,201,467		136,241,558
Total		69,100,376		81,140,913		12,832,687		1,201,467		164,275,443
Timing of revenue recognition:
Over the time		69,100,376		4,898,351		12,832,687		1,201,467		88,032,881
At a point in time		-		76,242,562		-		-		76,242,562
Total		69,100,376		81,140,913		12,832,687		1,201,467		164,275,443

Detailed information of revenues on each business segment for the years ended December 31, 2022, 2021 and 2020 is disclosed below:

i. Natural Gas Transportation:

	2022		2021		2020
Firm		33,984,311		38,806,353		56,118,114
Access and Charge		1,409,911		1,680,113		2,469,413
Interruptible and Others		5,249,240		7,243,478		10,512,849
Total		40,643,462		47,729,944		69,100,376

ii. Production and Commercialization of Liquids:

	2022		2021		2020
Product		94,302,054		99,586,058		75,278,560
Services		4,504,128		4,786,166		4,898,351
Government grants		5,408,677		4,187,526		964,002
Total		104,214,859		108,559,750		81,140,913

iii. Other services:

	2022		2021		2020
Conditioning and treatment		5,941,496		6,509,010		5,989,222
Operation and maintenance		450,840		481,338		490,937
Steam sales		372,779		429,014		535,488
Construction		2,363		87,610		75,893
UT Construction		43,537		79,694		207,231
Transportation and conditioning of Natural Gas		11,717,321		8,137,078		5,274,364
Others		218,718		413,891		259,552
Total		18,747,054		16,137,635		12,832,687

Cost of Sales

i) Net cost of sales

	2022			2021			2020
Inventories at the beginning of the year		2,278,309			1,680,352			1,231,440
Purchases		48,129,536			46,041,630			37,255,612
Operating costs (Note 8.j.)		47,467,264			47,399,731			44,243,091
Inventories at the end of the year		(1,833,545	)		(2,278,309	)		(1,680,352	)
Total		96,041,564			92,843,404			81,049,791

Expenses by Nature

j) Expenses by nature – Information required under art. 64 paragraph I, clause B) Commercial Companies Law

	2022
			Operating expenses
Accounts	Total		Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other compensations		13,296,943		5,584,104		4,529,381		2,438,849		744,609			-
Social security taxes		2,521,317		1,034,058		890,630		441,721		154,908			-
Compensation to Directors and Supervisory Committee		125,897		-		-		125,897		-			-
Professional services fees		1,644,291		48,972		600,631		898,431		96,257			-
Technical operator assistance fees		3,067,198		280,709		2,786,489		-		-			-
Materials		1,594,685		462,672		1,130,811		-		1,202			-
Third parties services		1,563,456		679,466		688,730		195,260		-			-
Telecommunications and post expenses		84,443		16,128		26,623		36,931		4,761			-
Rents		108,981		17,579		80,773		9,653		976			-
Transports and freight		613,856		349,132		252,357		11,993		374			-
Easements		200,955		156,726		44,229		-		-			-
Offices supplies		46,944		18,548		9,598		17,996		802			-
Travels expenses		198,078		102,338		35,091		46,229		14,420			-
Insurance		687,743		398,963		237,271		51,509		-			-
Property, plant and equipment maintenance		6,464,178		5,111,188		1,274,298		78,692		-			-
Depreciation of property, plant and equipment		19,572,669		13,185,736		5,187,205		1,199,728		-			-
Taxes and contributions		10,858,003		1,786,426		60,885		29,609		8,981,083	(1)		-
Advertising		189,091		-		-		-		189,091			-
Banks expenses		99,346		-		-		99,346		-			-
Interests expense		6,798,475		-		-		-		-			6,798,475
Foreign exchange loss		52,105,975		-		-		-		-			52,105,975
Costs of services rendered to third parties		48,922		-		48,922		-		-			-
Other expenses		438,298		124,348		226,247		72,589		15,114			-
Total 2022		122,329,744		29,357,093		18,110,171		5,754,433		10,203,597			58,904,450

⁽¹⁾ Includes tax on exports for Ps. 3,659,451 for the year ended December 31, 2022.

	2021
				Operating expenses
Accounts	Total			Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other contributions		11,614,557			5,027,119		3,883,677		2,072,132		631,629			-
Social security taxes		2,355,744			1,047,791		820,929		341,671		145,353			-
Compensation to Directors and Supervisory Committee		124,190			-		-		124,190		-			-
Professional services fees		996,024			70,276		103,990		781,403		40,355			-
Technical operator assistance fees		4,250,358			744,106		3,506,252		-		-			-
Materials		1,601,348			531,421		1,069,880		-		47			-
Third parties services		1,414,519			662,460		673,542		78,517		-			-
Telecommunications and post expenses		94,968			18,745		18,309		48,768		9,146			-
Rents		61,124			28,263		16,423		15,554		884			-
Transports and freight		496,898			287,470		201,379		7,712		337			-
Easements		355,420			334,008		21,412		-		-			-
Offices supplies		38,629			13,620		8,481		14,812		1,716			-
Travels expenses		109,433			60,943		21,137		22,368		4,985			-
Insurance		852,181			495,149		298,049		58,983		-			-
Property, plant and equipment maintenance		7,814,946			6,598,364		1,134,931		81,651		-			-
Depreciation of property, plant and equipment		18,721,149			12,564,973		4,876,977		1,279,199		-			-
Taxes and contributions		10,433,607			1,809,784		74,808		32,406		8,516,609	(1)		-
Advertising		103,548			-		-		-		103,548			-
Doubtful accounts		(129,715	)		-		-		-		(129,715	)		-
Banks expenses		23,340			-		-		23,340		-			-
Interests expense		8,703,402			-		-		-		-			8,703,402
Foreign exchange loss		24,239,337			-		-		-		-			24,239,337
Costs of services rendered to third parties		111,952			-		111,952		-		-			-
Other expenses		291,142			104,070		159,041		13,361		14,670			-
Total 2021		94,678,101			30,398,562		17,001,169		4,996,067		9,339,564			32,942,739

⁽¹⁾ Includes tax on exports of Ps. 3,069,765 for the year ended December 31, 2021.

	2020
			Operating expenses
Accounts	Total		Regulated Activities		Non Regulated Activities		Administrative expenses		Selling expenses			Financial expenses
Salaries, wages and other compensations		11,910,337		5,332,943		3,720,628		2,180,423		676,343			-
Social security taxes		2,422,583		1,044,064		744,398		487,600		146,521			-
Compensation to Directors and Supervisory Committee		117,725		-		-		117,725		-			-
Professional services fees		929,950		101,483		39,103		708,924		80,440			-
Technical operator assistance fees		4,205,901		1,733,124		2,472,777		-		-			-
Materials		1,332,039		482,988		849,051		-		-			-
Third parties services		1,523,368		692,579		772,421		56,718		1,650			-
Telecommunications and post expenses		139,427		39,218		30,941		61,112		8,156			-
Rents		74,086		29,685		15,245		26,924		2,232			-
Transports and freight		460,821		273,192		180,073		7,556		-			-
Easements		289,449		257,489		31,960		-		-			-
Offices supplies		26,629		9,077		3,787		12,962		803			-
Travels expenses		200,878		90,310		58,722		44,430		7,416			-
Insurance		752,400		431,938		267,609		52,812		41			-
Property, plant and equipment maintenance		5,505,454		4,733,387		676,821		95,246		-			-
Depreciation of property, plant and equipment		18,115,502		12,414,245		4,699,917		1,001,340		-			-
Taxes and contributions		8,830,693		1,487,002		76,682		3,758		7,263,251	(1)		-
Advertising		252,851		-		-		-		252,851			-
Doubtful accounts		279,520		-		-		-		279,520			-
Banks expenses		69,783		-		-		69,783		-			-
Interests expense		9,874,146		-		-		-		-			9,874,146
Foreign exchange loss		43,621,645		-		-		-		-			43,621,645
Costs of services rendered to third parties		319,508		-		319,508		-		-			-
Other expenses		157,879		66,103		64,621		20,500		6,655			-
Total 2020		111,412,574		29,218,827		15,024,264		4,947,813		8,725,879			53,495,791

⁽¹⁾ Includes tax on exports for Ps. 1,238,347 for the year ended December 31, 2020.

Net Financial Results

k) Net financial results

	2022			2021			2020
Financial income
Interest income		1,834,401			1,543,011			1,607,135
Foreign exchange gain		27,942,306			11,843,541			14,609,528
Subtotal		29,776,707			13,386,552			16,216,663
Financial expenses
Interest expense (1)		(6,798,475	)		(8,703,402	)		(9,874,146	)
Foreign exchange loss		(52,105,975	)		(24,239,337	)		(43,621,645	)
Subtotal		(58,904,450	)		(32,942,739	)		(53,495,791	)
Other financial results
Notes repurchase results		(1,030,169	)		(806,841	)		1,174,202
Derivative financial instruments results		(127,585	)		(157,227	)		1,321,859
Fair value gains / (losses) on financial instruments through profit or loss		24,127,905			2,319,880			(21,362,711	)
Others		(770,571	)		(960,662	)		(1,052,827	)
Subtotal		22,199,580			395,150			(19,919,477	)
Gain on net monetary position		3,768,283			18,311,140			19,058,813
Total		(3,159,880	)		(849,897	)		(38,139,792	)

⁽¹⁾ Includes Ps. 382,649, Ps. 568,315 and Ps. 712,528 of accrued interest corresponding to leasing liabilities, for the years ended December 31, 2022, 2021 and 2020.

Other Operating Results

l) Other operating results

	2022			2021			2020
Net increase in provisions (1)		(356,890	)		(612,036	)		(453,946	)
Recovery of insurance		29,000			730,846			696,771
Recovery action of VAT and income tax (Note 20.c)		-			144,912			-
Others		251,392			(12,797	)		50,697
Total		(76,498	)		250,925			293,522

⁽¹⁾ Including legal expenses

Financial Assets at Amortized Cost

m) Financial assets measured at amortized cost

	2022				2021
	Current		Non Current		Current		Non Current
Fixed term deposits in foreign currency		-		39,290,345		-		43,718,093
VRD bonds		1,438		-		3,721		2,306
Private debt bonds		-		871,938		-		-
Total		1,438		40,162,283		3,721		43,720,399

Financial Assets at Fair Value

n) Financial assets at fair value through profit or loss

	2022				2021
	Current		Non Current		Current		Non Current
Mutual funds in local market		-		-		152,868		-
Public debt bonds		7,162,504		-		6,432,817		-
Private debt bonds with related parties		2,570,796		-		1,388,558		-
Private debt bonds		25,808,410		-		17,870,749		-
Equity instruments		3,747,920		-		-		-
Total		39,289,630		-		25,844,992		-

Payroll and Social Security Taxes Payable

o) Payroll and social security taxes payable

	2022				2021
	Current		Non Current		Current		Non Current
Vacation benefit payable		1,296,356		-		1,186,142		-
Annual bonus payable		857,151		-		896,347		-
Social security taxes payable		471,945		-		685,123		-
UT		4,377		-		6,957		-
Total		2,629,829		-		2,774,569		-

XML

INVESTMENTS IN ASSOCIATES (Tables)

12 Months Ended

Dec. 31, 2022

INVESTMENTS IN ASSOCIATES [Abstract]

Investments in Associates

	2022						2021
	Description of securities
	Face		Amount		Book value		Book value
Name and issuer	value
Transporte y Servicios de Gas en Uruguay S.A.	Ps. Uru. 1			196,000		13,502		19,339
Emprendimientos de Gas del Sur S.A. (in liquidation)	$	1		116,130		700		1,132
Gas Link S.A.	$	1		502,962		140,300		43,900
Total						154,502		64,371

XML

JOINT ARRANGEMENTS (Tables)

12 Months Ended

Dec. 31, 2022

JOINT ARRANGEMENTS [Abstract]

Joint Arrangements

The breakdown of the amounts included in the statements of financial position related to the Company’s participation in the UT and its results is the following:

	2022		2021
Consolidated Statements of financial position
Non Current assets		-		-
Current Assets		72,020		368,325
Total		72,020		368,325
Non Current Liabilities		-		-
Current Liabilities		278,622		739,043
Total		278,622		739,043

	2022			2021			2020
Consolidated Statements of comprehensive income
Gross profit		27			53			13,415
Operating loss		(7,854	)		(15,299	)		(3,719	)
Net Financial results		141,140			274,931			220,157
Comprehensive income		133,286			259,632			216,438

XML

SHARE OF PROFIT FROM ASSOCIATES (Tables)

12 Months Ended

Dec. 31, 2022

SHARE OF PROFIT FROM ASSOCIATES [Abstract]

Profit from Associates

	2022			2021			2020
EGS (in liquidation)		(432	)		(308	)		(232	)
TGU		(5,837	)		(5,770	)		(1,418	)
Link		96,407			47,425			64,307
Total		90,138			41,347			62,657

XML

PROPERTY, PLANT AND EQUIPMENT (Tables)

12 Months Ended

Dec. 31, 2022

PROPERTY, PLANT AND EQUIPMENT [Abstract]

Property, Plant and Equipment

	2022
	Cost												Depreciation and Impairment
													Accumulated at									Accumulated at
	Beginning										End of the		the beginning									the end		Net
Account	of the year		Additions		Retirements			Transfers			year		of the year		Retirements			For the year		rate %		of the year		book value
Pipelines		265,066,631		-		-			4,361,804			269,428,435		144,855,499		-			6,548,184		2.2		151,403,683		118,024,752
Compressor plants		116,840,361		-		-			4,135,224			120,975,585		80,652,592		-			5,284,061	3.3 to 25			85,936,653		35,038,932
Other plants		106,030		-		-			-			106,030		46,113		-			3,289		3.3		49,402		56,628
Stations of regulation and/or measurement of pressure		9,502,577		-		-			165,914			9,668,491		7,489,062		-			260,160		4.0		7,749,222		1,919,269
Other technical installations		1,964,446		-		-			420,266			2,384,712		1,542,316		-			73,079		6.7		1,615,395		769,317
Subtotal assets related to natural gas transportation service		393,480,045		-		-			9,083,208			402,563,253		234,585,582		-			12,168,773				246,754,355		155,808,898
Non-regulated segment Pipelines		43,520,177		-		-			185,982			43,706,159		3,383,838		-			1,444,820		2.2		4,828,658		38,877,501
Non-regulated segment Compressor plants		8,422,007		-		-			72,584			8,494,591		4,969,891		-			870,535	3.3 to 25			5,840,426		2,654,165
Non-regulated segment Other plants		77,586,306		-		(1,863,128	)		10,121,226			85,844,404		44,982,655		(1,863,128	)		2,220,735		3.3		45,340,262		40,504,142
Non-regulated segment Stations of regulation and/or measurement of pressure		2,829,148		-		-			3,603			2,832,751		384,512		-			111,187		4.0		495,699		2,337,052
Non-regulated segment Other technical installations		1,040,891		-		-			47,379			1,088,270		577,826		-			90,090		6.7		667,916		420,354
Subtotal assets related to Other Services and Production and Commercialization of Liquids		133,398,529		-		(1,863,128	)		10,430,774			141,966,175		54,298,722		(1,863,128	)		4,737,367				57,172,961		84,793,214
Lands		1,417,568		-		-			-			1,417,568		-		-			-		-		-		1,417,568
Buildings and constructions		15,604,574		-		-			372,507			15,977,081		7,887,429		-			308,816		2.0		8,196,245		7,780,836
Facilities and features in building		1,157,039		-		-			20,995			1,178,034		526,674		-			35,163		4.0		561,837		616,197
Machinery, equipment and tools		5,353,477		237,299		-			28,117			5,618,893		3,461,019		-			554,096	6.7 to 10			4,015,115		1,603,778
UT Machinery, equipment and tools		3,641		-		-			-			3,641		3,641		-			-	6.7 to 10			3,641		-
Computers and Telecommunication systems		22,870,210		-		-			1,458,548			24,328,758		17,579,964		-			1,577,198	6.7 to 20			19,157,162		5,171,596
Vehicles		2,221,358		159,632		-			-			2,380,990		1,721,854		-			182,037		20		1,903,891		477,099
Furniture		955,440		7,472		-			41			962,953		902,025		-			9,219		10		911,244		51,709
Materials		15,791,047		6,275,734		(96,242	)		(5,242,745	)		16,727,794		-		-			-		-		-		16,727,794
Line pack		2,133,003		-		-			-			2,133,003		110,662		-			-		-		110,662		2,022,341
Works in progress		19,226,284		14,933,727		-			(16,151,445	)		18,008,566		-		-			-		-		-		18,008,566
Total		613,612,215		21,613,864		(1,959,370	)		-			633,266,709		321,077,572		(1,863,128	)		19,572,669				338,787,113		294,479,596

	2021
	Cost												Depreciation and Impairment
													Accumulated at									Accumulated at
	Beginning										End of the		the beginning									the end		Net
Account	of the year		Additions		Retirements			Transfers			year		of the year		Retirements			For the year		rate %		of the year		book value
Pipelines		263,565,765		-		(586	)		1,501,452			265,066,631		138,428,020		(341	)		6,427,820		2.2		144,855,499		120,211,132
Compressor plants		112,497,073		-		(74	)		4,343,362			116,840,361		75,761,325		(70	)		4,891,337		3.3 a 25		80,652,592		36,187,769
Other plants		106,030		-		-			-			106,030		42,726		-			3,387		3.3		46,113		59,917
Stations of regulation and/or measurement of pressure		8,933,021		-		-			569,556			9,502,577		7,240,802		-			248,260		4.0		7,489,062		2,013,515
Other technical installations		1,701,491		-		-			262,955			1,964,446		1,499,144		-			43,172		6.7		1,542,316		422,130
Subtotal assets related to natural gas transportation service		386,803,380		-		(660	)		6,677,325			393,480,045		222,972,017		(411	)		11,613,976				234,585,582		158,894,463
Non-regulated segment Pipelines		43,383,354		-		-			136,823			43,520,177		1,942,152		-			1,441,686		2.2		3,383,838		40,136,339
Non-regulated segment Compressor plants		8,361,565		-		-			60,442			8,422,007		4,093,187		-			876,704		3.3 a 25		4,969,891		3,452,116
Non-regulated segment Other plants		75,790,110		-		-			1,796,196			77,586,306		43,017,260		-			1,965,395		3.3		44,982,655		32,603,651
Non-regulated segment Stations of regulation and/or measurement of pressure		2,616,454		2,643		-			210,051			2,829,148		275,237		-			109,275		4.0		384,512		2,444,636
Non-regulated segment Other technical installations		1,016,791		-		-			24,100			1,040,891		485,393		-			92,433		6.7		577,826		463,065
Subtotal assets related to Other Services and Production and Commercialization of Liquids		131,168,274		2,643		-			2,227,612			133,398,529		49,813,229		-			4,485,493				54,298,722		79,099,807
Lands		1,417,568		-		-			-			1,417,568		-		-			-		-		-		1,417,568
Buildings and constructions		14,995,664		-		(12	)		608,922			15,604,574		7,588,478		(10	)		298,961		2.0		7,887,429		7,717,145
Facilities and features in building		1,055,941		-		(39	)		101,137			1,157,039		495,969		(37	)		30,742		4.0		526,674		630,365
Machinery, equipment and tools		4,687,684		425,882		-			239,911			5,353,477		2,999,073		-			461,946		6.7 a 10		3,461,019		1,892,458
UT Machinery, equipment and tools		3,641		-		-			-			3,641		3,641		-			-		6.7 a 10		3,641		-
Computers and Telecommunication systems		21,180,182		-		-			1,690,028			22,870,210		15,932,596		-			1,647,368		6.7 a 20		17,579,964		5,290,246
Vehicles		2,070,127		153,637		(2,406	)		-			2,221,358		1,547,470		(2,001	)		176,385		20.0		1,721,854		499,504
Furniture		918,308		37,054		-			78			955,440		895,747		-			6,278		10.0		902,025		53,415
Materials		13,940,845		6,478,730		(125,178	)		(4,503,350	)		15,791,047		-		-			-		-		-		15,791,047
Line pack		2,133,003		-		-			-			2,133,003		110,662		-			-		-		110,662		2,022,341
Works in progress		12,695,872		13,572,075		-			(7,041,663	)		19,226,284		-		-			-		-		-		19,226,284
Total		593,070,489		20,670,021		(128,295	)		-			613,612,215		302,358,882		(2,459	)		18,721,149				321,077,572		292,534,643

Composition of Net Book Value of Property, Plant and Equipment

The following is the composition of the resulting net book value of Property, plant and equipment as of December 31, 2022 and 2021:

	2022			2021
Cost		633,266,709			613,612,215
Accumulated depreciaton		(338,787,113	)		(321,077,572	)
Total		294,479,596			292,534,643

Quantitative Information of Right-of-use Assets

As of December 31, 2022 and 2021, the assets related to the Other Services and Production and Commercialization of Liquids segments contains the following assets for right of use:

	2022		2021
Other plants		986,979		1,256,155
Compressor plants		2,450,404		3,118,695
Other technical installations		278,631		354,621
Total		3,716,014		4,729,471

The book value variation of the rights-of use accounted during the years ended on December 31, 2022 and 2021 corresponds to its depreciation:

	2022			2021
Other plants		(269,176	)		(269,177	)
Compressor plants		(668,291	)		(668,293	)
Other technical installations		(75,990	)		(75,989	)
Total		(1,013,457	)		(1,013,459	)

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LOANS (Tables)

12 Months Ended

Dec. 31, 2022

LOANS [Abstract]

Short-term and Long-term Loans

Short-term and long-term loans as of December 31, 2022 and 2021 comprise the following:

	2022		2021
Current Loans
2018 Notes Interest		937,379		1,075,060
Bank loans		1,440,989		-
Other financial liabilities		377,415		-
Leasing (Note 21)		1,164,146		1,224,678
Total Current loans		3,919,929		2,299,738
Non Current Loans
2018 Notes		83,292,496		95,458,303
Leasing (Note 21)		3,098,069		4,662,971
Bank loans		4,303,571		-
Total non current loans		90,694,136		100,121,274
Total (1)		94,614,065		102,421,012

⁽¹⁾ As of December 31, 2022 and 2021, it is net of Notes repurchase of Ps 5,257,400 and Ps. 4,484,852, respectively.

⁽²⁾ Net of issuance expenses of Ps. 30,105 and Ps. 102,623 as of December 31, 2022 and 2021, respectively.

Activity of Loans

The activity of the loans as of December 31, 2022 and 2021 is the following:

	2022						2021
	Leases liabilities			Other payables			Leases liabilities			Other payables
Beginning balance		5,887,649			96,533,363			8,505,178			120,481,460
Inflation adjustment restatement		(4,769,942	)		(58,645,278	)		(3,164,211	)		(44,998,198	)
Accrued interest		382,649			5,875,804			568,315			7,321,812
Effect of foreign exchange effect		4,005,769			47,656,779			1,730,223			22,095,210
VAT unpaid installments		23,182			-			26,212			-
Proceeds from loans		-			6,164,853			-			-
Acquisition of notes result		-			1,030,169			-			806,841
Payment of loans(1)		(901,526	)		(86,187	)		(1,163,922	)		-
Acquisition of notes		-			(2,452,516	)		-			(1,869,224	)
Interest paid(2)		(365,566	)		(5,725,137	)		(614,146	)		(7,304,538	)
Ending balance		4,262,215			90,351,850			5,887,649			96,533,363

⁽¹⁾ For the years ended on December 31, 2022 and 2021, Ps. 901,526 and Ps. 1,163,922 respectively were cancelled through the offseting of debit balances maintained with the creditor (Pampa Energía).

⁽²⁾ For the years ended on December 31, 2022 and 2021, Ps. 365,566 and Ps. 614,146, respectively, were cancelled through the offseting of debit balances maintained with the creditor (Pampa Energía).

Maturities of Current and Non-Current Loans

The maturities of the current and non-current loans as of December 31, 2022 are as follows, not including issuance expenses:

			To due
	Due at 12/31/2022		From 1/01/2023 to 12/31/2023		From 1/01/2024 to 12/31/2024		From 1/01/2025 to 12/31/2025		From 1/01/2026 to 12/31/2026		From 1/01/2027 onwards		Total
2018 Notes		-		937,379		-		83,292,496		-		-		84,229,875
Financial Leasing		133,549		1,030,597		1,117,025		1,210,816		770,228		-		4,262,215
Other financial liabilities		-		377,415		-		-		-		-		377,415
Bank loans		-		1,440,989		4,303,571		-		-		-		5,744,560
Total		133,549		3,786,380		5,420,596		84,503,312		770,228		-		94,614,065

Future Minimum Lease Payments and Present Book Value

The following table sets reconciliation between the total of future minimum lease payments as of December 31, 2022, and their present book value:

	12/31/2022
As of 12/31/2023		1,458,705
From 1/01/2024 to 12/31/2024		1,325,334
From 1/01/2025 to 12/31/2025		1,325,334
From 1/01/2026 to 12/31/2026		791,728
From 1/01/2027 onwards		-
Total minimum future payments		4,901,101
Future financial charges on financial leases		(638,886	)
Book Value financial leases		4,262,215

As of December 31, 2022 and 2021, the Company and its controlled companies are in compliance with the covenants established in all of their financial debt.

Conditions of 2018 Notes

On May 2, 2018, within the framework of the 2017 Program, the Company issued the 2018 Notes according to the following characteristics:

	2018 Notes
Amount in U.S.$	500,000,000
Interest Rate	6.75% annual
Issuance price	99.725%

	Scheduled payment date	Percentage of the principal to be paid
Amortization	May 2, 2025	100%
Frequency of interest payment	Semiannual, payable on May 2 and November 2 of each year.
Guarantor	None

Detailed of Other Financial Liabilities

As of December 31, 2022, Other financial liabilities includes:

Currency	Amount (in thousands)		Interest rate		Expiration date
USD		1,797		5.75% - 7.75%	Between May and September 2023
Euros		284		3.05% - 3.85%	April / May 2023
USD		8,000		4.30%	August 2023

Disclosure of Bank Loans

On March 31, 2022, the subsidiary Telcosur, took a loan for US$24 million. The main terms of said loan are:

Amount in US$		24.000.000
Interest rate	1.5% annual
Amortizacion date	January 25, 2024
Interest payment frequency	To the expiration
Guarantee	Fixed term in foreign currency (1)

⁽¹⁾ Included as “Non-current financial assets measured at amortised cost”.

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INCOME TAX AND DEFERRED TAX (Tables)

12 Months Ended

Dec. 31, 2022

INCOME TAX AND DEFERRED TAX [Abstract]

Income Tax Expense

The reconciliation between the charge computed for tax purposes and the income tax expense charged to the statement of comprehensive income in the years ended December 31, 2022, 2021 and 2020 is as follows:

	2022			2021			2020
Current income tax		(15,857,624	)		(26,694,111	)		(10,113,083	)
Deferred income tax		(1,203,529	)		1,883,262			(2,836,978	)
Total income tax		(17,061,153	)		(24,810,849	)		(12,950,061	)

Net Deferred Tax Assets and Liabilities

The analysis of the net deferred tax assets and liabilities is as follows:

	2022			2021
Deferred tax assets:
Deferred tax assets to be recovered after more than 12 months		3,626,709			7,846,119
Deferred tax assets to be recovered after less than 12 months		1,412,828			1,247,816
Deferred tax liabilities:
Deferred tax liabilities taxable after more than 12 months		(25,574,208	)		(28,787,450	)
Deferred tax liabilities taxable after less than 12 months		(686,246	)		(323,873	)
Deferred tax liabilities, net		(21,220,917	)		(20,017,388	)

Components of Net Deferred Tax Assets and Liabilities

The components of the net deferred tax assets and liabilities as of December 31, 2022, 2021 and 2020 are the following:

Deferred tax assets	Other receivables			Account receivables discounted value			Provisions for legal claims and other provisions			Financial leases			Contract liabilities		Tax loss carryforward			Tax inflation adjustment			Financial assets at fair value through profit or loss		Total
As of December 31, 2020		39,744			1,891			656,071			2,140,878			1,880,469		2,776			49,211			-		4,771,040
Charge in results		(39,744	)		(115	)		351,911			(133,032	)		869,196		3,294,662			(19,983	)		-		4,322,895
As of December 31, 2021		-			1,776			1,007,982			2,007,846			2,749,665		3,297,438			29,228			-		9,093,935
Charge in results		-			(1,776	)		(366,049	)		(562,847	)		6,764		(3,297,438	)		(16,667	)		183,615		(4,054,398	)
As of December 31, 2022		-			-			641,933			1,444,999			2,756,429		-			12,561			183,615		5,039,537

Deferred tax liabilities	Other receivables			Loans			Property, Plant and Equipment			Cash and cash equivalents			Inventories			Financial assets at amortized cost			Tax inflation adjustment			Other liabilities			Total
As of December 31, 2020		-			(58,641	)		(15,369,172	)		(3,047	)		(98,569	)		(592,588	)		(10,549,673	)		-			(26,671,690	)
Charge in results		(5,226	)		(104,771	)		(6,035,973	)		(30,571	)		(28,274	)		592,588			3,424,894			(252,300	)		(2,439,633	)
As of December 31, 2021		(5,226	)		(163,412	)		(21,405,145	)		(33,618	)		(126,843	)		-			(7,124,779	)		(252,300	)		(29,111,323	)
Charge in results		(114,164	)		23,424			(1,417,423	)		(392,781	)		6,984			-			4,492,529			252,300			2,850,869
As of December 31, 2022		(119,390	)		(139,988	)		(22,822,568	)		(426,399	)		(119,859	)		-			(2,632,250	)		-			(26,260,454	)

Effective Income Tax Rate Reconciliation

Income tax expense computed at the statutory tax rate on pre-tax income differs from the income tax expense for the years ended December 31, 2022, 2021 and 2020 as follows:

	2022			2021			2020
Pre tax income		49,378,955			65,583,161			22,612,275
Statutory income tax rate		35	%		35	%		30	%
Pre tax income at statutory income tax rate		(17,282,634	)		(22,954,106	)		(6,783,682	)
Tax effects due to:
- Restatement by inflation		2,968,108			11,276,529			6,159,982
- Tax loss variation		-			3,297,438			-
- Unrecognized tax loss carryforward		-			-			(5,988,032	)
- Adjustment affidavit previous year		(82,082	)		(131,655	)		(26,677	)
- Tax inflation adjustment		(2,717,831	)		(7,678,237	)		(8,159,343	)
- Variation of tax rate		-			(7,955,019	)		-
- Others		53,286			(665,799	)		1,847,691
Total income tax		(17,061,153	)		(24,810,849	)		(12,950,061	)

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PROVISIONS (Tables)

12 Months Ended

Dec. 31, 2022

PROVISIONS [Abstract]

Provisions

The total amount of the Provisions is included in current liabilities.

	For legal claims and others
Balances as of 12/31/2020		2,530,671
Inflation adjustment restatement		(1,023,648	)
Additions		1,036,496		(1)
Uses		(9,751	)
Decreases		(9,535	)	(3)
Balances as of 12/31/2021		2,524,233
Inflation adjustment restatement		(1,445,722	)
Additions		804,831		(2)
Uses		(20,248	)
Decreases		(29,000	)	(3)
Balances as of 12/31/2022		1,834,094

⁽¹⁾ Ps. 557,718 are included in “Other operating expenses” and Ps. 478,778 in “Financial expenses”.

⁽²⁾ Ps. 356,890 are included in “Other operating expenses” and Ps. 447,941 in “Financial expenses”.

⁽³⁾ The total are included in “Other operating expenses”.

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FINANCIAL RISK MANAGEMENT (Tables)

12 Months Ended

Dec. 31, 2022

FINANCIAL RISK MANAGEMENT [Abstract]

Fixed-Rate and Floating-Rate Financial Assets and Liabilities

The following table shows a breakdown of the Company’s fixed-rate and floating-rate financial assets and liabilities as of December 31, 2022 and 2021:

	Financial assets				Financial liabilities (1)
	2022		2021		2022		2021
Fix interest rate		39,323,688		43,932,998		86,048,279		96,533,363
Variable interest rate		2,665,814		34,048,991		-		-
Total		41,989,502		77,981,989		86,048,279		96,533,363

⁽¹⁾ Includes 2018 Notes. For further information see Note 13 to the Consolidated Financial Statements.

Provision for Losses

On this basis, the provision for losses for the year ended December 31, 2022 for trade receivables was determined as follows:

Ratio	Non-due			90 days			120 days			180 days			+240 days
Natural Gas Transportation segment		0	%		0.50	%		5	%		10	%		100	%
Other segments		0	%		0.25	%		2	%		5	%		100	%

Current and Non-Current Sales Receivables

As of December 31, 2022 and 2021, current and non-current sales receivables, net of allowance for doubtful accounts, amounted to:

	2022			2021
Current trade receivables		17,071,816			20,951,996
Allowances for doubful accounts (1)		(132,521	)		(258,142	)
Total		16,939,295			20,693,854

⁽¹⁾
Said amount represents the best estimate made by tgs according to what is stated in Note 4.b).

Significant Customers

In the ordinary course of business, the Company provides natural gas transportation services mainly to natural gas distribution companies, CAMMESA and Pampa Energía. The amounts of net sales made to the principal customers to which Natural Gas Transportation services were provided in the years ended December 31,2022, 2021 and 2020 and the sales receivable balances (net of allowances) as of December 31, 2022 and 2021 are set forth below:

	2022				2021				2020
	Revenues		Trade receivables		Revenues		Trade receivables		Revenues
MetroGas		10,355,756		768,193		11,821,815		2,809,625		17,330,099
Camuzzi Gas Pampeana S.A.		7,668,510		567,671		8,708,964		681,780		12,813,975
Naturgy Argentina		6,286,027		483,552		7,051,418		586,216		10,358,472
CAMMESA		3,795,168		1,380,126		5,400,240		1,194,018		6,887,604
Pampa Energía		1,471,413		111,450		1,666,555		637,807		2,473,548
Camuzzi Gas del Sur S.A.		1,816,770		118,208		2,012,977		294,958		3,066,612

The amounts of Liquids Production and Marketing net sales made to major customers during the years ended December 31, 2022, 2021 and 2020 and sales receivable balances (net of allowances) as of December 31, 2022 and 2021 are set forth below:

	2022				2021				2020
	Revenues		Trade receivables		Revenues		Trade receivables		Revenues
PBB Polisur		25,589,826		3,569,289		26,657,675		2,778,544		27,355,042
Petredec		-		-		-		-		2,032,373
Geogas Trading S.A.		3,668,557		-		7,402,250		5,235,421		845,467
Italgas S.A.		-		-		295,028		-		1,165,237
YPF		2,598,667		160,887		3,700,237		66,832		2,862,061
Petrobras Global Trading BV		280,416		-		10,953,530		-		13,263,199
Trafigura Beheer		15,968,772		898,027		13,490,509		1,347,151		-
Pampa Energía		3,583,230		281,774		4,996,215		659,046		-

Maturities of Financial Assets

Below is a detail of the maturities of the financial assets included in (i) cash and cash equivalents, (ii) other financial assets, (iii) trade receivables and  (iv) other receivables as of December 31, 2022 and 2021:

December 31, 2022
	Cash and cash equivalents		Other financial assets		Credits (1) (2)
Without specified maturity		2,988,946		39,289,630		40,389
With specified maturity
Overdue
Until 12-31-2021		-		-		173,477
From 01-01-22 to 03-31-22		-		-		8,167
From 04-01-22 to 06-30-22		-		-		26,427
From 07-01-22 to 09-30-22		-		-		22,530
From 10-01-22 to 12-31-22		-		-		1,449,545
Total overdue		-		-		1,680,146
Non-due
From 01-01-23 to 03-31-23		-		192		19,536,293
From 04-01-23 to 06-30-23		-		192		113,994
From 07-01-23 to 09-30-23		-		1,054		57,932
From 10-01-23 to 12-31-23		-		-		3,753
During 2024		-		40,162,283		14,026
During 2025		-		-		-
During 2026		-		-		-
From 2027 onwards		-		-		-
Total non-due		-		40,163,721		19,725,998
Total with specified maturity		-		40,163,721		21,406,144
Total		2,988,946		79,453,351		21,446,533

⁽¹⁾ The total amount of the receivables without specified maturity is recorded in Non-current assets.

⁽²⁾ Includes financial assets recorded in trade receivables and other receivables, excluding allowance for doubtful accounts.

December 31, 2021
	Cash and cash equivalents		Other financial assets		Credits (1) (2)
Without specified maturity		8,627,004		24,456,434		73,421
With specified maturity
Overdue
Until 12-31-2020		-		-		264,751
From 01-01-21 to 03-31-21		-		-		-
From 04-01-21 to 06-30-21		-		-		-
From 07-01-21 to 09-30-21		-		-		81,875
From 10-01-21 to 12-31-21		-		-		3,376,015
Total overdue		-		-		3,722,641
Non-due
From 01-01-22 to 03-31-22		-		1,350		19,607,691
From 04-01-22 to 06-30-22		-		1,143		587,968
From 07-01-22 to 09-30-22		-		732		112,848
From 10-01-22 to 12-31-22		-		497		939
During 2023		-		45,108,956		14,377
During 2024		-		-		-
During 2025		-		-		-
From 2026 onwards		-		-		-
Total non-due		-		45,112,678		20,323,823
Total with specified maturity		-		45,112,678		24,046,464
Total		8,627,004		69,569,112		24,119,885

⁽¹⁾ The total amount of the receivables without specified maturity is recorded in Non-current assets.

⁽²⁾ Includes financial assets recorded in trade receivables and other receivables, excluding allowance for doubtful accounts.

Maturities of Financial Liabilities

Below is a detail of the maturities of the Company’s financial liabilities corresponding to: commercial debts, remunerations, other debts and financial debts as of December 31, 2022 and 2021. The amounts presented in the tables represent contractual undiscounted cash flows and, therefore, do not correspond to the amounts presented in the statement of financial position. These estimates are made on the basis of information available at the end of each year and may not reflect actual amounts in the future. Therefore, the amounts shown are provided for illustrative purposes only:

December 31, 2022
	Loans		Other financial liabilities		Leases liabilities
Without specified maturity		-		-		-
With specified maturity
Overdue
Until 12-31-2021		-		230,673		-
From 01-01-22 to 03-31-22		-		311		-
From 04-01-22 to 06-30-22		-		311		-
From 07-01-22 to 09-30-22		-		311		-
From 10-01-22 to 12-31-22		-		311		133,549
Total overdue		-		231,917		133,549
Non-due
From 01-01-23 to 03-31-23		-		12,547,599		331,289
From 04-01-23 to 06-30-23		3,316,733		78,747		331,289
From 07-01-23 to 09-30-23		1,541,798		-		331,289
From 10-01-23 to 12-31-23		2,989,575		-		331,289
During 2024		5,979,150		-		1,325,334
During 2025		91,569,575		-		1,325,334
During 2026		-		-		791,728
From 2027 onwards		-		-		-
Total non-due		105,396,831		12,626,346		4,767,552
Total with specified maturity		105,396,831		12,858,263		4,901,101
Total		105,396,831		12,858,263		4,901,101

December 31, 2021
	Loans		Other financial liabilities		Financial leases
Without specified maturity		-		-		-
With specified maturity
Overdue
Until 12-31-2020		-		576,851		-
From 01-01-21 to 03-31-21		-		606		-
From 04-01-21 to 06-30-21		-		606		-
From 07-01-21 to 09-30-21		-		606		-
From 10-01-21 to 12-31-21		-		606		150,834
Total overdue		-		579,275		150,834
Non-due
From 01-01-22 to 03-31-22		82,329		14,066,957		374,170
From 04-01-22 to 06-30-22		3,376,545		82,164		374,170
From 07-01-22 to 09-30-22		-		-		374,170
From 10-01-22 to 12-31-22		3,376,545		-		374,170
During 2023		6,753,090		-		1,496,884
During 2024		6,753,090		-		1,496,884
During 2025		103,422,323		-		1,496,884
From 2026 onwards		-		-		894,210
Total non-due		123,763,922		14,149,121		6,881,542
Total with specified maturity		123,763,922		14,728,396		7,032,376
Total		123,763,922		14,728,396		7,032,376

Gearing Ratio

During the years ended December 31, 2022 and 2021, the gearing ratio was as follows:

	2022		2021
Total debt (Note 13)		94,614,065		102,421,012
Total equity		267,224,289		234,906,487
Total capital		361,838,354		337,327,499
Gearing Ratio		0.26		0.30

Categories of Financial Assets and Liabilities

The categorization of financial assets and liabilities as of December 31, 2022 and 2021 is included below:

	December 31, 2022
	Financial assets at fair value		Financial assets at amortized cost		Total
CURRENT ASSETS
Trade receivables		-		16,939,295		16,939,295
Other receivables		-		4,359,818		4,359,818
Financial assets at amortized cost		-		1,438		1,438
Financial assets at fair value through profit or loss		39,289,630		-		39,289,630
Cash and cash equivalents		2,665,814		323,132		2,988,946
Total current assets		41,955,444		21,623,683		63,579,127
NON-CURRENT ASSETS
Other receivables		-		14,899		14,899
Other financial assets at amortized cost		-		40,162,283		40,162,283
Total non-current assets		-		40,177,182		40,177,182
Total assets		41,955,444		61,800,865		103,756,309

	Financial liabilities at fair value		Other financial liabilities		Total
CURRENT LIABILITIES
Trade payables		-		10,524,936		10,524,936
Loans		-		3,919,929		3,919,929
Payroll and social security taxes payables		-		2,153,524		2,153,524
Other payables		-		286,555		286,555
Total current liabilities		-		16,884,944		16,884,944
NON-CURRENT LIABILITIES
Loans		-		90,694,136		90,694,136
Total non-current liabilities		-		90,694,136		90,694,136
Total liabilities		-		107,579,080		107,579,080

	2021
	Financial assets at fair value		Financial assets at amortirzed cost		Total
CURRENT ASSETS
Trade receivables		-		20,693,854		20,693,854
Other receivables		-		3,151,559		3,151,559
Financial assets at amortized cost		-		3,721		3,721
Financial assets at fair value through profit or loss		25,844,992		-		25,844,992
Cash and cash equivalents		8,197,972		429,032		8,627,004
Total current assets		34,042,964		24,278,166		58,321,130
NON-CURRENT ASSETS
Other receivables		-		16,330		16,330
Financial assets at amortized cost		-		43,720,399		43,720,399
Total non-current assets		-		43,736,729		43,736,729
Total assets		34,042,964		68,014,895		102,057,859

	Financial liabilities at fair value		Other financial liabilities		Total
CURRENT LIABILITIES
Trade payables		-		11,820,683		11,820,683
Loans		-		2,299,738		2,299,738
Derivative financial results		82,329		-		82,329
Payroll and social security taxes payables		-		2,279,022		2,279,022
Other payables		-		619,970		619,970
Total current liabilities		82,329		17,019,413		17,101,742
NON-CURRENT LIABILITIES
Loans		-		100,121,274		100,121,274
Total non-current liabilities		-		100,121,274		100,121,274
Total liabilities		82,329		117,140,687		117,223,016

Fair Value of Financial Assets and Liabilities

The table below shows different assets at their fair value classified by hierarchy as of December 31, 2022 and 2021:

	As of December 31, 2022
	Level 1		Level 2		Level 3		Total
Financial assets at fair value
Cash and cash equivalents		2,665,814		-		-		2,665,814
Financial assets at fair value through profit or loss		39,289,630		-		-		39,289,630
Total		41,955,444		-		-		41,955,444

	As of December 31, 2021
	Level 1		Level 2		Level 3		Total
Financial assets at fair value
Cash and cash equivalents		8,197,972		-		-		8,197,972
Financial assets at fair value through profit or loss		25,844,992		-		-		25,844,992
Total		34,042,964		-		-		34,042,964

	Level 1		Level 2		Level 3		Total
Financial liabilities at fair value
Derivative financial instruments		82,329		-		-		82,329
Total		82,329		-		-		82,329

The estimated fair value of Non-current loans is estimated based on quoted market prices (level 1). The following table reflects the carrying amount and estimated fair value of the 2018 Notes at December 31, 2022, based on their quoted market price:

	As of December 31, 2022
	Carrying amount		Fair value
2018 Notes		84,229,875		77,460,798

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ASSETS AND LIABILITIES IN FORREIGN CURRENCY (Tables)

12 Months Ended

Dec. 31, 2022

ASSETS AND LIABILITIES IN FORREIGN CURRENCY [Abstract]

Balances of Assets and Liabilities in Foreign Currency

The balances in foreign currency as of December 31, 2022 and 2021 are detailed below:

	2022							2021
	Foreign currency					Amount		Foreign currency		Amount
	and amount		Exchange			in local		and amount		in local
	(in thousands)		rate			currency		(in thousands)		currency
CURRENT ASSETS
Cash and cash equivalents	US$	1,613		176.960	(1)		285,436	US$	1,512		301,949
Financial assets at fair value through profit or loss (3)	US$	176,852		176.960	(1)		31,295,730		65,522		13,084,872
Trade receivables	US$	66,107		176.960	(1)		11,698,295	US$	66,395		13,259,212
Total current assets	US$	244,572					43,279,461	US$	133,429		26,646,033
NON CURRENT ASSETS
Financial assets at amortized cost (4)	US$	226,957		176.960	(1)		40,162,283	US$	218,917		43,718,092
Total non current assets	US$	226,957					40,162,283	US$	218,917		43,718,092
TOTAL ASSETS	US$	471,529					83,441,744	US$	352,346		70,364,125
CURRENT LIABILITIES
Trade payables	US$	38,655		177.160	(2)		6,848,120	US$	37,807		7,564,861
	Euros	432		189.916	(2)		82,043		-		-
Loans	US$	21,819		177.160	(2)		3,865,516	US$	11,493		2,299,738
	Euros	287		189.916	(2)		54,413		-		-
Total current liabilities	US$	60,474					10,713,636	US$	49,300		9,864,599
	Euros	719					136,456		-		-
NON CURRENT LIABILITIES
Loans	US$	511,933		177.160	(2)		90,694,136	US$	500,377		100,121,274
Contract liabilities	US$	10,106		177.160	(2)		1,790,361		-		-
Total non current liabilities	US$	522,039					92,484,497	US$	500,377		100,121,274
TOTAL LIABILITIES	US$	582,513					103,198,133	US$	549,677		109,985,873
	Euros	719					136,456		-		-

⁽¹⁾ Buy exchange rate at the end of fiscal year

⁽²⁾ Sell exchange rate at the end of fiscal year

⁽³⁾ Includes public and private debt bonds Dólar Linked for Ps. 27,013,330.

⁽⁴⁾ Includes time deposits Dólar Linked for Ps. 865,009.

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COMMON STOCK AND DIVIDENDS (Tables)

12 Months Ended

Dec. 31, 2022

COMMON STOCK AND DIVIDENDS [Abstract]

Common Stock

As of December 31, 2022, 2021 and 2020, tgs’ common stock was as follows:

Common Stock structure as of December 31, 2022, 2021 and 2020
Shares Class	Amount of common stock, subscribed, issued, paid in, and authorized for
	public offer
Common Shares Class
(Face value $ 1, 1 vote)	Outstandings shares		Treasury Shares		Common Stock
Class “A”		405,192,594		-		405,192,594
Class “B”		347,568,464		41,734,225		389,302,689
Total		752,761,058		41,734,225		794,495,283

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BALANCES AND TRANSACTIONS WITH RELATED COMPANIES (Tables)

12 Months Ended

Dec. 31, 2022

BALANCES AND TRANSACTIONS WITH RELATED COMPANIES [Abstract]

Balances with Related Parties

The detail of significant outstanding balances for transactions entered into by tgs and its related parties as of December 31, 2022 and 2021 is as follows:

	2022				2021
Company	Accounts receivable		Accounts payable		Accounts receivable		Accounts payable
Controlling shareholder:
CIESA		37		-		-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía (1)		1,299,505		4,889,458		659,046		6,830,195
Associate which exercises significant influence on the controlling shareholder:
Link		4,683		-		5,088		-
TGU		-		28,199		-		31,849
Other related companies:
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		19,695		17,518		24,165		35,932
CT Barragán S.A.		4,294		-		7,385		-
SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A.		2,227		-		-		-
Transener S.A.		30		-		-		61
Total		1,330,471		4,935,175		695,684		6,898,037

⁽¹⁾ Accounts payable includes Ps. 4,262,215 and Ps. 5,887,648 corresponding to the financial leasing recorded as “Loans” as of December 31, 2022 and 2021, respectively.

Transactions with Related Parties

The detail of significant transactions with related parties for the years ended December 31, 2022, 2021 and 2020 is as follows:

Year ended December 31, 2022:

			Revenues				Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense		Interest gain / Gain / (loss) on fair value	Selling expenses (1)
Controlling shareholder:
CIESA		-		-		-		-		-		-		162	-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		1,471,413		3,583,230		3,972,829		5,826,231		3,067,198		-		-	-		-
Associates with significant influence:
Link		-		-		46,750		-		-		-		-	-		-
Other related companies:
SACDE Sociedad Argentina de Construcción y Desarrollo Estratégico S.A.		-		-		7,203		-		-		-		-	-		-
Transener S.A.		-		-		417		-		-		-		-	-		-
CT Barragán S.A.		-		-		17,459		-		-		-		-	96,408		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		298,568		-		-		-		-		-		-	-		-
Fundación TGS		-		-		-		-		-		-		-	-		31,059
Total		1,769,981		3,583,230		4,044,658		5,826,231		3,067,198		-		162	96,408		31,059

⁽¹⁾ Corresponds to donations expenses.

Year ended December 31, 2021:

			Revenues				Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense		Interest gain / Gain / (loss) on fair value		Selling expenses (1)
Controlling shareholder:
CIESA		-		-		-		-		-		277		-		-		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		1,666,555		4,996,215		2,365,465		5,628,181		4,250,358		-		568,315		-		-
Associates with significant influence:
Link		-		-		-		-		-		-		-		-		-
Other related companies:
Oleoductos del Valle S.A.		51,542		-		54,102		-		-		-		-		-		-
Transener S.A.		-		-		701		-		-		-		-		-		-
CT Barragán S.A.		-		-		26,659		-		-		-		-		484,082		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		289,761		-		-		-		-		-		-		-		-
Fundación TGS		-		-		-		-		-		-		-		-		2,277
Total		2,007,858		4,996,215		2,446,927		5,628,181		4,250,358		277		568,315		484,082		2,277

⁽¹⁾ Corresponds to donations expenses.

Year ended December 31, 2020:

	Revenues						Costs						Financial results
Company	Natural Gas Transportation		Production and commercialization of liquids		Other services		Gas purchase and others		Compensation for technical assistance		Revenues for administrative services		Interest expense
Controlling shareholder:
CIESA		-		-		-		-		-		411		-
Company which exercises joint control on the controlling shareholder:
Pampa Energía		2,473,548		3,087,152		1,807,202		470,636		4,205,901		-		712,528
Associates with significant influence:
Link		-		-		57,517		-		-		-		-
Other related companies:
Oleoductos del Valle S.A.		75,765		-		-		-		-		-		-
Transener S.A.		-		-		1,034		-		-		-		-
Petrolera Entre Lomas S.A.		7,277		-		26,268		-		-		-		-
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.)		331,583		-		-		-		-		-		-
Central Térmica Piedrabuena S.A.		5,131		-		-		-		-		-		-
Total		2,893,304		3,087,152		1,892,020		470,636		4,205,901		411		712,528

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CONTRACTUAL OBLIGATIONS (Tables)

12 Months Ended

Dec. 31, 2022

CONTRACTUAL OBLIGATIONS [Abstract]

Contractual Commitments

As of December 31, 2022, the Company had the following contractual commitments:

	Estimated maturity date
	Total		Due less than one year		As of 12/31/2023		From 01/01/2024 to 12/31/2024		From 01/01/2025 to 12/31/2025		From 01/01/2026 to 12/31/2026
Financial indebtedness (1)		109,769,494		-		7,848,106		10,351,813		91,569,575		-
Purchase obligations (2)		18,144,797		-		16,289,422		1,855,375		-		-
Financial Leases		4,901,101		133,549		1,325,156		1,325,334		1,325,334		791,728
Total		132,815,392		133,549		25,462,684		13,532,522		92,894,909		791,728

⁽¹⁾ Corresponds to the cancellation of principal and interest of the financial indebtedness. For further information, see Note 13.

⁽²⁾ Corresponds to purchase of natural gas contracts for the processing of liquids.

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BUSINESS DESCRIPTION, Summary (Details)	12 Months Ended
	Dec. 31, 2022 Extension
Business Overview [Abstract]
Term of transportation license granted	35 years
Number of extension entitled	1
Term of the extension	10 years

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BUSINESS DESCRIPTION, Major Shareholders (Details)	12 Months Ended
	Dec. 31, 2022
Transporte y Servicios de Gas en Uruguay S.A. (TGU) [Member]
Major Shareholders [Abstract]
Percentage of ownership in associate	49.00%
EGS S.A. [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	51.00%
Percentage of ownership in associate	49.00%
Gas Link S.A. [Member]
Major Shareholders [Abstract]
Percentage of ownership in associate	49.00%
TELCOSUR S.A. [Member]
Major Shareholders [Abstract]
Percentage of ownership	99.98%
TGSLatam Energia S.A. [Member]
Major Shareholders [Abstract]
Percentage of ownership	80.00%
CTG Energia S.A.U. [Member]
Major Shareholders [Abstract]
Percentage of ownership	100.00%
Pampa Energia [Member] | Transporte y Servicios de Gas en Uruguay S.A. (TGU) [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	51.00%
Pampa Energia [Member] | TELCOSUR S.A. [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	0.02%
Public Offering [Member]
Major Shareholders [Abstract]
Percentage of ownership	44.00%
Public Offering [Member] | FGS-ANSES [Member]
Major Shareholders [Abstract]
Percentage of ownership	24.00%
Public Offering [Member] | BYMA [Member]
Major Shareholders [Abstract]
Percentage of ownership	8.00%
Public Offering [Member] | NYSE [Member]
Major Shareholders [Abstract]
Percentage of ownership	12.00%
Treasury Shares [Member]
Major Shareholders [Abstract]
Percentage of ownership	5.00%
CIESA [Member]
Major Shareholders [Abstract]
Percentage of ownership	51.00%
CIESA [Member] | Pampa Energia [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	50.00%
CIESA [Member] | GIP and PCT [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	50.00%
CTG Energia S.A.U. [Member] | TGSLatam Energia S.A. [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	15.00%
TELCOSUR S.A. [Member] | TGSLatam Energia S.A. [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	5.00%
Shell Argentina S.A. [Member] | Gas Link S.A. [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	25.50%
Percentage of ownership in associate	25.50%
Pan American Sur S.A. [Member] | Gas Link S.A. [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	20.40%
Percentage of ownership in associate	20.40%
Wintershall Dea Argentina S.A. [Member] | Gas Link S.A. [Member]
Major Shareholders [Abstract]
Percentage of joint ownership	5.10%

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BUSINESS DESCRIPTION, Economic Context (Details)		3 Months Ended	12 Months Ended
	Nov. 30, 2022	Sep. 30, 2022	Dec. 31, 2022 Participants $ / shares	Dec. 31, 2021
Economic context [Abstract]
Cumulative inflation rate			94.80%
Economic activity, poverty and unemployment [Abstract]
Percentage increase (decrease) of economic activity	(2.60%)			10.40%
Unemployment rate		7.10%
Percentage of population living in poverty			36.50%
Fiscal imbalance [Abstract]
Percentage of primary fiscal deficit			2.40%	4.20%
Monetary imbalance and inflation [Abstract]
Survey of Market Expectations, number of participants | Participants			37
Expected inflation rate			110.00%
Exchange Market [Abstract]
Purchase price of foreign currency for buyer (in dollars per share)			$ 176.96
Purchase price of foreign currency for seller (in dollars per share)			$ 177.16
U.S. Dollars [Member]
Exchange Market [Abstract]
Depreciation of peso against U.S. dollar			72.00%
Alternative Currencies [Member]
Exchange Market [Abstract]
Exchange rate gap			100.00%

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SIGNIFICANT ACCOUNTING POLICIES, Consolidation (Details)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Telcosur [Member]
Subsidiaries [Abstract]
Company	Telcosur	Telcosur
Incorporation country	Argentina	Argentina
Closing date	December 31	December 31
Main activity	Telecommunication Services	Telecommunication Services
Telcosur [Member] | Direct [Member]
Subsidiaries [Abstract]
Shareholding and voting	99.98%	99.98%
Telcosur [Member] | Indirect [Member]
Subsidiaries [Abstract]
Shareholding and voting	0.00%	0.00%
CTG [Member]
Subsidiaries [Abstract]
Company	CTG	CTG
Incorporation country	Argentina	Argentina
Closing date	December 31	December 31
Main activity	Electricity related services	Electricity related services
CTG [Member] | Direct [Member]
Subsidiaries [Abstract]
Shareholding and voting	100.00%	100.00%
CTG [Member] | Indirect [Member]
Subsidiaries [Abstract]
Shareholding and voting	0.00%	0.00%
TGSLatam [Member]
Subsidiaries [Abstract]
Company	TGSLatam	TGSLatam
Incorporation country	Bolivia	Bolivia
Closing date	December 31	December 31
Main activity	Hydrocarbons and Electrical power related services	Hydrocarbons and Electrical power related services
TGSLatam [Member] | Direct [Member]
Subsidiaries [Abstract]
Shareholding and voting	80.00%	80.00%
TGSLatam [Member] | Indirect [Member]
Subsidiaries [Abstract]
Shareholding and voting	100.00%	100.00%
TGU [Member]
Associates [Abstract]
Company	TGU
Shareholding and voting	49.00%
Country	Uruguay
Main activity	Pipeline maintenance
Closing date	December 31
EGS [Member]
Associates [Abstract]
Company	EGS (“in liquidation”)
Shareholding and voting	49.00%
Country	Argentina
Main activity	Pipeline exploitation and construction
Closing date	December 31
Link [Member]
Associates [Abstract]
Company	Link
Shareholding and voting	49.00%
Country	Argentina
Main activity	Pipeline exploitation and construction
Closing date	December 31

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SIGNIFICANT ACCOUNTING POLICIES, Regulatory Framework (Details)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Regulatory framework [Abstract]
Inflation rate	94.79%	50.94%	36.14%

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SIGNIFICANT ACCOUNTING POLICIES, Property, Plant and Equipment (Details) $ in Thousands, $ in Millions	Dec. 31, 2022 ARS ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 ARS ($)
Property, plant and equipment [Abstract]
Property, plant and equipment from privatization of GdE	$ 294,479,596		$ 292,534,643
GdE [Member]
Property, plant and equipment [Abstract]
Percentage of common stock considered for assets value	70.00%	70.00%
Value of assets, price paid on common stock from privatization of GdE		$ 561.2
Value of common stock from privatization of GdE		801.7
Debt assumed from privatization of GdE		395.0
Property, plant and equipment from privatization of GdE		$ 1,196.7

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SIGNIFICANT ACCOUNTING POLICIES, Income Tax and Deferred Income Tax (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Income tax and deferred income tax [Abstract]
Provisions for income taxes	$ 0	$ 0

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SIGNIFICANT ACCOUNTING POLICIES, Equity Accounts (Details)	12 Months Ended
	Dec. 31, 2022
Equity accounts [Abstract]
Percentage of legal reserve of net income	5.00%
Percentage of legal reserve on sum of Capital stock and Adjustment to capital stock balances	20.00%

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SIGNIFICANT ACCOUNTING POLICIES, Basic and Diluted Earnings Per Share (Details) - ARS ($) $ / shares in Units, $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Earnings per share [Abstract]
Net income attributable to owners of the Company		$ 32,317,790	$ 40,772,306	$ 9,662,187
Average number of outstanding shares (in shares)	[1],[2]	752,761,058	752,761,058	762,371,755
Basic earnings per share (in pesos per share)		$ 42.93	$ 54.16	$ 12.68
Diluted earnings per share (in pesos per share)		$ 42.93	$ 54.16	$ 12.68

[1] The weighted average number of shares considers the effect of the weighted average of the changes originated in the transactions with the treasury shares made during the year.

[2] The weighted average of the number of shares considers the effect of the weighted average of the changes originated in the transactions with treasury shares made during the year.

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CRITICAL ACCOUNTING ESTIMATES AND JUDGMENTS (Details) $ in Thousands		12 Months Ended
	Jun. 16, 2021 ARS ($) Segment	Dec. 31, 2022 ARS ($)	Dec. 31, 2021 ARS ($)	Dec. 31, 2020 ARS ($)	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
CRITICAL ACCOUNTING ESTIMATES AND JUDGMENTS [Abstract]
Percentage points in probability of occurrence in base scenario		65.00%
Percentage points in probability of occurrence in optimistic scenario		20.00%
Percentage points in probability of occurrence in pessimistic scenario		15.00%
Book value of PPE [Abstract]
Impairment charge		$ 0	$ 0	$ 9,156,072
Income tax [Abstract]
Number of segments for accumulated net taxable income | Segment	3
Percentage of accumulated net taxable income		35.00%	35.00%	30.00%	30.00%	30.00%	35.00%
Accumulated net income		$ 17,282,634	$ 22,954,106	$ 6,783,682
Segment 1 [Member]
Income tax [Abstract]
Percentage of accumulated net taxable income	25.00%
Segment 1 [Member] | Top of Range [Member]
Income tax [Abstract]
Accumulated net income	$ 5,000
Segment 2 [Member]
Income tax [Abstract]
Percentage of accumulated net taxable income	30.00%
Segment 2 [Member] | Bottom of Range [Member]
Income tax [Abstract]
Accumulated net income	$ 5,000
Segment 2 [Member] | Top of Range [Member]
Income tax [Abstract]
Accumulated net income	$ 50,000
Segment 3 [Member]
Income tax [Abstract]
Percentage of accumulated net taxable income	35.00%
Segment 3 [Member] | Bottom of Range [Member]
Income tax [Abstract]
Accumulated net income	$ 50,000
Natural Gas Transportation [Member]
Book value of PPE [Abstract]
Impairment charge				$ 9,155,000
Natural Gas Transportation [Member] | Carrying Amount [member]
Book value of PPE [Abstract]
Cash generating units		$ 189,314,745,000

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SUPPLEMENTAL CASH FLOW INFORMATION (Details) - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Non-cash Investing and Financing Activities [Abstract]
Unpaid acquisition of PPE		$ 1,846,947	$ 1,856,040	$ 895,394
Principal payment of financial lease	[1]	$ 901,526	$ 1,163,922	$ 561,495

[1] Cancelled through compensation with trade receivables with the creditor. See Note 13.

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CONSOLIDATED BUSINESS SEGMENT INFORMATION (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2022 ARS ($) Segment	Dec. 31, 2021 ARS ($)	Dec. 31, 2020 ARS ($)
Operating segments [Abstract]
Revenues	$ 164,524,789	$ 173,319,821	$ 164,275,443
Cost of sales	(96,041,564)	(92,843,404)	(81,049,791)
Administrative expenses	(5,754,433)	(4,996,067)	(4,947,813)
Selling expenses	(10,203,597)	(9,339,564)	(8,725,879)
Other operating results (expenses) / income	(76,498)	250,925	293,522
Impairment of PPE	0	0	(9,156,072)
Operating profit	52,448,697	66,391,711	60,689,410
Depreciation of property, plant and equipment	(19,572,669)	(18,721,149)	(18,115,502)
Identifiable assets	412,092,225	405,519,916	378,098,311
Identifiable liabilities	$ 144,867,936	170,613,429	183,964,125
Natural Gas Transportation [Member]
Operating segments [Abstract]
Revenues		47,729,944
Impairment of PPE			(9,155,000)
Reportable Segments [Member]
Operating segments [Abstract]
Number of reportable segments | Segment	4
Reportable Segments [Member] | Natural Gas Transportation [Member]
Operating segments [Abstract]
Revenues	$ 40,643,462	47,729,944	69,100,376
Cost of sales	(29,357,094)	(30,398,565)	(29,218,827)
Administrative expenses	(4,230,811)	(3,820,247)	(3,652,010)
Selling expenses	(3,019,249)	(3,353,756)	(4,290,739)
Other operating results (expenses) / income	(180,352)	(396,796)	(129,779)
Impairment of PPE			(9,156,072)
Operating profit	5,020,716	11,514,432	25,136,276
Depreciation of property, plant and equipment	(14,385,464)	(13,844,172)	(13,415,586)
Identifiable assets	224,390,925	242,560,322	243,316,895
Identifiable liabilities	68,642,296	78,050,198	81,196,369
Reportable Segments [Member] | Production and Commercialization of Liquids [Member]
Operating segments [Abstract]
Revenues	104,214,859	108,559,750	81,140,913
Cost of sales	(58,784,800)	(56,280,587)	(46,554,104)
Administrative expenses	(829,258)	(664,124)	(746,192)
Selling expenses	(5,737,983)	(4,889,198)	(3,457,748)
Other operating results (expenses) / income	37,940	626,862	411,530
Impairment of PPE			0
Operating profit	38,900,758	47,352,703	30,794,399
Depreciation of property, plant and equipment	(1,308,511)	(1,194,842)	(1,125,453)
Identifiable assets	79,765,071	74,892,859	52,023,450
Identifiable liabilities	7,941,685	21,404,091	15,989,754
Reportable Segments [Member] | Other Services [Member]
Operating segments [Abstract]
Revenues	18,747,054	16,137,635	12,832,687
Cost of sales	(8,407,580)	(7,294,631)	(6,938,313)
Administrative expenses	(627,243)	(465,910)	(512,372)
Selling expenses	(1,336,806)	(1,010,116)	(881,361)
Other operating results (expenses) / income	65,914	20,099	7,383
Impairment of PPE			0
Operating profit	8,441,339	7,387,077	4,508,024
Depreciation of property, plant and equipment	(3,878,694)	(3,682,135)	(3,574,463)
Identifiable assets	102,867,810	87,327,237	82,037,118
Identifiable liabilities	63,768,842	70,954,650	86,567,711
Reportable Segments [Member] | Telecommunications [Member]
Operating segments [Abstract]
Revenues	919,414	892,492	1,201,467
Cost of sales	(656,850)	(623,473)	(821,874)
Administrative expenses	(67,121)	(45,786)	(37,239)
Selling expenses	(109,559)	(86,494)	(96,031)
Other operating results (expenses) / income	0	760	4,388
Impairment of PPE			0
Operating profit	85,884	137,499	250,711
Depreciation of property, plant and equipment	0	0	0
Identifiable assets	5,068,419	739,498	720,848
Identifiable liabilities	4,515,113	204,490	210,291
Eliminations [Member]
Operating segments [Abstract]
Revenues	(1,164,760)	(1,753,852)	(2,483,327)
Cost of sales	1,164,760	1,753,852	2,483,327
Administrative expenses	0	0	0
Selling expenses	0	0	0
Other operating results (expenses) / income	0	0	0
Impairment of PPE			0
Operating profit	0	0	0
Depreciation of property, plant and equipment	0	0	0
Eliminations [Member] | Natural Gas Transportation [Member]
Operating segments [Abstract]
Revenues	1,164,760	1,753,852	2,483,327
Eliminations [Member] | Production and Commercialization of Liquids [Member]
Operating segments [Abstract]
Revenues	0	0	0
Eliminations [Member] | Other Services [Member]
Operating segments [Abstract]
Revenues	0	0	0
Eliminations [Member] | Telecommunications [Member]
Operating segments [Abstract]
Revenues	$ 0	$ 0	$ 0

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Other Receivables (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current [Abstract]
Turnover tax balance	$ 220,927	$ 246,803
Income tax credit balance	96,687	42,697
VAT credit balance	1,495,500	1,368,925
Other tax receivables	107,249	73,562
Prepaid expenses	1,524,421	814,670
Advances to suppliers	8,338,576	5,887,123
Subsidies receivables	3,768,159	2,427,450
Other Receivables UT	33,460	56,924
Others	591,659	724,109
Total	16,176,638	11,642,263
Non Current [Abstract]
Turnover tax balance	0	0
Income tax credit balance	0	0
VAT credit balance	0	0
Other tax receivables	55	919
Prepaid expenses	0	0
Advances to suppliers	0	0
Subsidies receivables	0	0
Balances with related parties	0	0
Other Receivables UT	0	0
Others	14,844	16,330
Total	$ 14,899	$ 17,249

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Trade Receivables (Details) - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022		Dec. 31, 2021
Current [Abstract]
Commons		$ 15,741,345		$ 20,256,312
Related parties		1,330,471		695,684
Allowance for doubtful accounts		(132,521)		(258,142)
Total		16,939,295		20,693,854
Non Current [Abstract]
Commons		0		0
Related parties		0		0
Allowance for doubtful accounts		0		0
Total		0		0
Allowance for doubtful accounts [Abstract]
Balance at the beginning of the period		258,142	[1]	389,643
Inflation adjustment restatement		(125,621)		(131,501)
Additions		0		0
Applications		0		0
Reversals		0		0
Balance at the end of period	[1]	132,521		258,142
UT [Member]
Current [Abstract]
Commons		9,448		205,075
Non Current [Abstract]
Commons		0		0
Natural Gas Transportation [Member]
Current [Abstract]
Commons		4,398,150		6,681,903
Related parties		131,145		158,708
Non Current [Abstract]
Commons		0		0
Related parties		0		0
Production and Commercialization of Liquids [Member]
Current [Abstract]
Commons		8,189,884		10,793,068
Related parties		281,774		210
Non Current [Abstract]
Commons		0		0
Related parties		0		0
Other Services [Member]
Current [Abstract]
Commons		3,143,863		2,576,266
Related parties		917,552		536,766
Non Current [Abstract]
Commons		0		0
Related parties		$ 0		$ 0

[1] Said amount represents the best estimate made by tgs according to what is stated in Note 4.b).

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Cash and Cash Equivalents (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Cash and cash equivalents [Abstract]
Cash and banks	$ 289,630	$ 213,984
UT Cash and banks	159	142
Mutual funds in local currency	2,654,934	8,138,623
Interest-bearing accounts	33,343	214,906
UT Mutual funds	10,880	59,349
Total	$ 2,988,946	$ 8,627,004	$ 13,682,131	$ 39,088,735

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Contract Liabilities (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Current liabilities [abstract]
Contract liabilities	$ 1,045,454	$ 978,575
Non Current liabilities [abstract]
Contract liabilities	11,717,412	10,963,157
Revenue recognized from contracts with customers	469,978	477,516
Natural Gas Transportation [Member]
Current liabilities [abstract]
Contract liabilities	360,887	360,886
Non Current liabilities [abstract]
Contract liabilities	5,902,032	6,262,944
Production and Commercialization of Liquids [Member]
Current liabilities [abstract]
Contract liabilities	345,243	263,596
Non Current liabilities [abstract]
Contract liabilities	557,671	902,915
Other Services [Member]
Current liabilities [abstract]
Contract liabilities	326,802	327,971
Non Current liabilities [abstract]
Contract liabilities	5,257,709	3,797,298
UT [Member]
Current liabilities [abstract]
Contract liabilities	12,522	26,122
Non Current liabilities [abstract]
Contract liabilities	$ 0	$ 0

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Other Payables (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current [Abstract]
Payable for compensation for the Board of Directors and Supervisory Committee	$ 68,039	$ 37,809
Others	1,763	1,983
UT other liabilities	216,753	580,178
Total	286,555	619,970
Non Current [Abstract]
Payable for compensation for the Board of Directors and Supervisory Committee	0	0
Others	0	0
UT other liabilities	0	0
Total	$ 0	$ 0

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Taxes Payables (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current [Abstract]
Health and safety tax	$ 52,339	$ 41,921
Withholdings and perceptions made to third parties	581,800	621,114
Turnover Tax	158,382	267,965
Tax on exports	103,759	337,941
Others	48,416	28,485
Total	944,696	1,297,426
Non-current [Abstract]
Health and safety tax	0	0
Withholdings and perceptions made to third parties	0	0
Turnover Tax	0	0
Tax on exports	0	0
Others	14,285	0
Total	$ 14,285	$ 0

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Trade Payables (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current [Abstract]
Suppliers	$ 9,717,662	$ 10,662,184
UT Suppliers	119,077	129,333
Customers (credit balances)	15,237	18,778
Related companies (Note 21)	672,960	1,010,388
Total	10,524,936	11,820,683
Non-current [Abstract]
Suppliers	0	0
UT Suppliers	0	0
Customers (credit balances)	0	0
Related companies (Note 21)	0	0
Total	$ 0	$ 0

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Revenues (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenues [Abstract]
Sales of goods and services	$ 159,116,112	$ 169,132,295	$ 163,311,441
Subsidies	5,408,677	4,187,526	964,002
Total	$ 164,524,789	$ 173,319,821	$ 164,275,443

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Disaggregation of Revenues by Geographical Market (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenues [Abstract]
Revenues	$ 164,524,789	$ 173,319,821	$ 164,275,443
Over the Time [Member]
Revenues [Abstract]
Revenues	64,814,058	69,546,237	88,032,881
At a Point in Time [Member]
Revenues [Abstract]
Revenues	99,710,731	103,773,584	76,242,562
External Market [Member]
Revenues [Abstract]
Revenues	46,313,662	44,708,635	28,033,885
Local Market [Member]
Revenues [Abstract]
Revenues	118,211,127	128,611,186	136,241,558
Natural Gas Transportation [Member]
Revenues [Abstract]
Revenues		47,729,944
Reportable Segments [Member] | Natural Gas Transportation [Member]
Revenues [Abstract]
Revenues	40,643,462	47,729,944	69,100,376
Reportable Segments [Member] | Natural Gas Transportation [Member] | Over the Time [Member]
Revenues [Abstract]
Revenues	40,643,462	47,729,944	69,100,376
Reportable Segments [Member] | Natural Gas Transportation [Member] | At a Point in Time [Member]
Revenues [Abstract]
Revenues	0	0	0
Reportable Segments [Member] | Natural Gas Transportation [Member] | External Market [Member]
Revenues [Abstract]
Revenues	0	0	0
Reportable Segments [Member] | Natural Gas Transportation [Member] | Local Market [Member]
Revenues [Abstract]
Revenues	40,643,462	47,729,944	69,100,376
Reportable Segments [Member] | Production and Commercialization of Liquids [Member]
Revenues [Abstract]
Revenues	104,214,859	108,559,750	81,140,913
Reportable Segments [Member] | Production and Commercialization of Liquids [Member] | Over the Time [Member]
Revenues [Abstract]
Revenues	4,504,128	4,786,166	4,898,351
Reportable Segments [Member] | Production and Commercialization of Liquids [Member] | At a Point in Time [Member]
Revenues [Abstract]
Revenues	99,710,731	103,773,584	76,242,562
Reportable Segments [Member] | Production and Commercialization of Liquids [Member] | External Market [Member]
Revenues [Abstract]
Revenues	46,313,662	44,708,635	28,033,885
Reportable Segments [Member] | Production and Commercialization of Liquids [Member] | Local Market [Member]
Revenues [Abstract]
Revenues	57,901,197	63,851,115	53,107,028
Reportable Segments [Member] | Other Services [Member]
Revenues [Abstract]
Revenues	18,747,054	16,137,635	12,832,687
Reportable Segments [Member] | Other Services [Member] | Over the Time [Member]
Revenues [Abstract]
Revenues	18,747,054	16,137,635	12,832,687
Reportable Segments [Member] | Other Services [Member] | At a Point in Time [Member]
Revenues [Abstract]
Revenues	0	0	0
Reportable Segments [Member] | Other Services [Member] | External Market [Member]
Revenues [Abstract]
Revenues	0	0	0
Reportable Segments [Member] | Other Services [Member] | Local Market [Member]
Revenues [Abstract]
Revenues	18,747,054	16,137,635	12,832,687
Reportable Segments [Member] | Telecommunications [Member]
Revenues [Abstract]
Revenues	919,414	892,492	1,201,467
Reportable Segments [Member] | Telecommunications [Member] | Over the Time [Member]
Revenues [Abstract]
Revenues	919,414	892,492	1,201,467
Reportable Segments [Member] | Telecommunications [Member] | At a Point in Time [Member]
Revenues [Abstract]
Revenues	0	0	0
Reportable Segments [Member] | Telecommunications [Member] | External Market [Member]
Revenues [Abstract]
Revenues	0	0	0
Reportable Segments [Member] | Telecommunications [Member] | Local Market [Member]
Revenues [Abstract]
Revenues	$ 919,414	$ 892,492	$ 1,201,467

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Disaggregation of Revenues by Business Segment (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenues [Abstract]
Revenues	$ 164,524,789	$ 173,319,821	$ 164,275,443
Natural Gas Transportation [Member]
Revenues [Abstract]
Revenues		47,729,944
Reportable Segments [Member] | Natural Gas Transportation [Member]
Revenues [Abstract]
Revenues	40,643,462	47,729,944	69,100,376
Reportable Segments [Member] | Natural Gas Transportation [Member] | Firm [Member]
Revenues [Abstract]
Revenues	33,984,311	38,806,353	56,118,114
Reportable Segments [Member] | Natural Gas Transportation [Member] | Access and Charge [Member]
Revenues [Abstract]
Revenues	1,409,911	1,680,113	2,469,413
Reportable Segments [Member] | Natural Gas Transportation [Member] | Interruptible and Others [Member]
Revenues [Abstract]
Revenues	5,249,240	7,243,478	10,512,849
Reportable Segments [Member] | Production and Commercialization of Liquids [Member]
Revenues [Abstract]
Revenues	104,214,859	108,559,750	81,140,913
Reportable Segments [Member] | Production and Commercialization of Liquids [Member] | Product [Member]
Revenues [Abstract]
Revenues	94,302,054	99,586,058	75,278,560
Reportable Segments [Member] | Production and Commercialization of Liquids [Member] | Services [Member]
Revenues [Abstract]
Revenues	4,504,128	4,786,166	4,898,351
Reportable Segments [Member] | Production and Commercialization of Liquids [Member] | Government Grants [Member]
Revenues [Abstract]
Revenues	5,408,677	4,187,526	964,002
Reportable Segments [Member] | Other Services [Member]
Revenues [Abstract]
Revenues	18,747,054	16,137,635	12,832,687
Reportable Segments [Member] | Other Services [Member] | Conditioning and Treatment [Member]
Revenues [Abstract]
Revenues	5,941,496	6,509,010	5,989,222
Reportable Segments [Member] | Other Services [Member] | Operation and Maintenance [Member]
Revenues [Abstract]
Revenues	450,840	481,338	490,937
Reportable Segments [Member] | Other Services [Member] | Steam Sales [Member]
Revenues [Abstract]
Revenues	372,779	429,014	535,488
Reportable Segments [Member] | Other Services [Member] | Construction [Member]
Revenues [Abstract]
Revenues	2,363	87,610	75,893
Reportable Segments [Member] | Other Services [Member] | UT Construction [Member]
Revenues [Abstract]
Revenues	43,537	79,694	207,231
Reportable Segments [Member] | Other Services [Member] | Transportation and conditioning of Natural Gas [Member]
Revenues [Abstract]
Revenues	11,717,321	8,137,078	5,274,364
Reportable Segments [Member] | Other Services [Member] | Others [Member]
Revenues [Abstract]
Revenues	218,718	413,891	259,552
Reportable Segments [Member] | Telecommunications [Member]
Revenues [Abstract]
Revenues	$ 919,414	$ 892,492	$ 1,201,467

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Cost of Sales (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Reconciliation of Changes in Inventories [Abstract]
Inventories at the beginning of the year	$ 2,278,309	$ 1,680,352	$ 1,231,440
Purchases	48,129,536	46,041,630	37,255,612
Operating costs	47,467,264	47,399,731	44,243,091
Inventories at the end of the year	(1,833,545)	(2,278,309)	(1,680,352)
Total	$ 96,041,564	$ 92,843,404	$ 81,049,791

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DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Expenses by Nature (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022		Dec. 31, 2021		Dec. 31, 2020
Expenses by Nature [abstract]
Salaries, wages and other compensations	$ 13,296,943		$ 11,614,557		$ 11,910,337
Social security taxes	2,521,317		2,355,744		2,422,583
Compensation to Directors and Supervisory Committee	125,897		124,190		117,725
Professional services fees	1,644,291		996,024		929,950
Technical operator assistance fees	3,067,198		4,250,358		4,205,901
Materials	1,594,685		1,601,348		1,332,039
Third parties services	1,563,456		1,414,519		1,523,368
Telecommunications and post expenses	84,443		94,968		139,427
Rents	108,981		61,124		74,086
Transports and freight	613,856		496,898		460,821
Easements	200,955		355,420		289,449
Offices supplies	46,944		38,629		26,629
Travels expenses	198,078		109,433		200,878
Insurance	687,743		852,181		752,400
Property, plant and equipment maintenance	6,464,178		7,814,946		5,505,454
Depreciation of property, plant and equipment	19,572,669		18,721,149		18,115,502
Taxes and contributions	10,858,003		10,433,607		8,830,693
Advertising	189,091		103,548		252,851
Doubtful accounts	0		(129,715)		279,520
Banks expenses	99,346		23,340		69,783
Interests expense	6,798,475		8,703,402		9,874,146
Foreign exchange loss	52,105,975		24,239,337		43,621,645
Costs of services rendered to third parties	48,922		111,952		319,508
Other expenses	438,298		291,142		157,879
Total	122,329,744		94,678,101		111,412,574
Tax on exports	3,659,451		3,069,765		1,238,347
Operating Expenses, Regulated Activities [Member]
Expenses by Nature [abstract]
Salaries, wages and other compensations	5,584,104		5,027,119		5,332,943
Social security taxes	1,034,058		1,047,791		1,044,064
Compensation to Directors and Supervisory Committee	0		0		0
Professional services fees	48,972		70,276		101,483
Technical operator assistance fees	280,709		744,106		1,733,124
Materials	462,672		531,421		482,988
Third parties services	679,466		662,460		692,579
Telecommunications and post expenses	16,128		18,745		39,218
Rents	17,579		28,263		29,685
Transports and freight	349,132		287,470		273,192
Easements	156,726		334,008		257,489
Offices supplies	18,548		13,620		9,077
Travels expenses	102,338		60,943		90,310
Insurance	398,963		495,149		431,938
Property, plant and equipment maintenance	5,111,188		6,598,364		4,733,387
Depreciation of property, plant and equipment	13,185,736		12,564,973		12,414,245
Taxes and contributions	1,786,426		1,809,784		1,487,002
Advertising	0		0		0
Doubtful accounts			0		0
Banks expenses	0		0		0
Interests expense	0		0		0
Foreign exchange loss	0		0		0
Costs of services rendered to third parties	0		0		0
Other expenses	124,348		104,070		66,103
Total	29,357,093		30,398,562		29,218,827
Operating Expenses, Non Regulated Activities [Member]
Expenses by Nature [abstract]
Salaries, wages and other compensations	4,529,381		3,883,677		3,720,628
Social security taxes	890,630		820,929		744,398
Compensation to Directors and Supervisory Committee	0		0		0
Professional services fees	600,631		103,990		39,103
Technical operator assistance fees	2,786,489		3,506,252		2,472,777
Materials	1,130,811		1,069,880		849,051
Third parties services	688,730		673,542		772,421
Telecommunications and post expenses	26,623		18,309		30,941
Rents	80,773		16,423		15,245
Transports and freight	252,357		201,379		180,073
Easements	44,229		21,412		31,960
Offices supplies	9,598		8,481		3,787
Travels expenses	35,091		21,137		58,722
Insurance	237,271		298,049		267,609
Property, plant and equipment maintenance	1,274,298		1,134,931		676,821
Depreciation of property, plant and equipment	5,187,205		4,876,977		4,699,917
Taxes and contributions	60,885		74,808		76,682
Advertising	0		0		0
Doubtful accounts			0		0
Banks expenses	0		0		0
Interests expense	0		0		0
Foreign exchange loss	0		0		0
Costs of services rendered to third parties	48,922		111,952		319,508
Other expenses	226,247		159,041		64,621
Total	18,110,171		17,001,169		15,024,264
Administrative Expenses [Member]
Expenses by Nature [abstract]
Salaries, wages and other compensations	2,438,849		2,072,132		2,180,423
Social security taxes	441,721		341,671		487,600
Compensation to Directors and Supervisory Committee	125,897		124,190		117,725
Professional services fees	898,431		781,403		708,924
Technical operator assistance fees	0		0		0
Materials	0		0		0
Third parties services	195,260		78,517		56,718
Telecommunications and post expenses	36,931		48,768		61,112
Rents	9,653		15,554		26,924
Transports and freight	11,993		7,712		7,556
Easements	0		0		0
Offices supplies	17,996		14,812		12,962
Travels expenses	46,229		22,368		44,430
Insurance	51,509		58,983		52,812
Property, plant and equipment maintenance	78,692		81,651		95,246
Depreciation of property, plant and equipment	1,199,728		1,279,199		1,001,340
Taxes and contributions	29,609		32,406		3,758
Advertising	0		0		0
Doubtful accounts			0		0
Banks expenses	99,346		23,340		69,783
Interests expense	0		0		0
Foreign exchange loss	0		0		0
Costs of services rendered to third parties	0		0		0
Other expenses	72,589		13,361		20,500
Total	5,754,433		4,996,067		4,947,813
Selling Expenses [Member]
Expenses by Nature [abstract]
Salaries, wages and other compensations	744,609		631,629		676,343
Social security taxes	154,908		145,353		146,521
Compensation to Directors and Supervisory Committee	0		0		0
Professional services fees	96,257		40,355		80,440
Technical operator assistance fees	0		0		0
Materials	1,202		47		0
Third parties services	0		0		1,650
Telecommunications and post expenses	4,761		9,146		8,156
Rents	976		884		2,232
Transports and freight	374		337		0
Easements	0		0		0
Offices supplies	802		1,716		803
Travels expenses	14,420		4,985		7,416
Insurance	0		0		41
Property, plant and equipment maintenance	0		0		0
Depreciation of property, plant and equipment	0		0		0
Taxes and contributions	8,981,083	[1]	8,516,609	[2]	7,263,251	[3]
Advertising	189,091		103,548		252,851
Doubtful accounts			(129,715)		279,520
Banks expenses	0		0		0
Interests expense	0		0		0
Foreign exchange loss	0		0		0
Costs of services rendered to third parties	0		0		0
Other expenses	15,114		14,670		6,655
Total	10,203,597		9,339,564		8,725,879
Financial Expenses [Member]
Expenses by Nature [abstract]
Salaries, wages and other compensations	0		0		0
Social security taxes	0		0		0
Compensation to Directors and Supervisory Committee	0		0		0
Professional services fees	0		0		0
Technical operator assistance fees	0		0		0
Materials	0		0		0
Third parties services	0		0		0
Telecommunications and post expenses	0		0		0
Rents	0		0		0
Transports and freight	0		0		0
Easements	0		0		0
Offices supplies	0		0		0
Travels expenses	0		0		0
Insurance	0		0		0
Property, plant and equipment maintenance	0		0		0
Depreciation of property, plant and equipment	0		0		0
Taxes and contributions	0		0		0
Advertising	0		0		0
Doubtful accounts			0		0
Banks expenses	0		0		0
Interests expense	6,798,475		8,703,402		9,874,146
Foreign exchange loss	52,105,975		24,239,337		43,621,645
Costs of services rendered to third parties	0		0		0
Other expenses	0		0		0
Total	$ 58,904,450		$ 32,942,739		$ 53,495,791

[1] Includes tax on exports for Ps. 3,659,451 for the year ended December 31, 2022.

[2] Includes tax on exports of Ps. 3,069,765 for the year ended December 31, 2021.

[3] Includes tax on exports for Ps. 1,238,347 for the year ended December 31, 2020.

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Net Financial Results (Details) - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Financial income [Abstract]
Interest income		$ 1,834,401	$ 1,543,011	$ 1,607,135
Foreign exchange gain		27,942,306	11,843,541	14,609,528
Subtotal		29,776,707	13,386,552	16,216,663
Financial expenses [Abstract]
Interest expense	[1]	(6,798,475)	(8,703,402)	(9,874,146)
Foreign exchange loss		(52,105,975)	(24,239,337)	(43,621,645)
Subtotal		(58,904,450)	(32,942,739)	(53,495,791)
Other financial results [Abstract]
Notes repurchase results		(1,030,169)	(806,841)	1,174,202
Derivative financial instruments results		(127,585)	(157,227)	1,321,859
Fair value gains / (losses) on financial instruments through profit or loss		24,127,905	2,319,880	(21,362,711)
Others		(770,571)	(960,662)	(1,052,827)
Subtotal		22,199,580	395,150	(19,919,477)
Gain on net monetary position		3,768,283	18,311,140	19,058,813
Total net financial results		(3,159,880)	(849,897)	(38,139,792)
Accrued interest on lease liabilities		$ 382,649	$ 568,315	$ 712,528

[1] Includes Ps. 382,649, Ps. 568,315 and Ps. 712,528 of accrued interest corresponding to leasing liabilities, for the years ended December 31, 2022, 2021 and 2020.

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Other Operating Results (Details) - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS [Abstract]
Net increase in provisions	[1]	$ (356,890)	$ (612,036)	$ (453,946)
Recovery of insurance		29,000	730,846	696,771
Recovery action of VAT and income tax		0	144,912	0
Others		251,392	(12,797)	50,697
Total		$ (76,498)	$ 250,925	$ 293,522

[1] Including legal expenses

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Other Financial Assets at Amortized Cost (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current [Abstract]
Financial assets measured at amortized cost	$ 1,438	$ 3,721
Non Current [Abstract]
Other financial assets at amortized cost	40,162,283	43,720,399
Other Financial Assets at Amortized Cost [Member]
Current [Abstract]
Financial assets measured at amortized cost	1,438	3,721
Non Current [Abstract]
Other financial assets at amortized cost	40,162,283	43,720,399
Fixed Term Deposits in Foreign Currency [Member]
Current [Abstract]
Financial assets measured at amortized cost	0	0
Non Current [Abstract]
Other financial assets at amortized cost	39,290,345	43,718,093
VRD Bonds [Member]
Current [Abstract]
Financial assets measured at amortized cost	1,438	3,721
Non Current [Abstract]
Other financial assets at amortized cost	0	2,306
Private Debt Bonds [Member]
Current [Abstract]
Financial assets measured at amortized cost	0	0
Non Current [Abstract]
Other financial assets at amortized cost	$ 871,938	$ 0

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Other Financial Assets at Fair Value (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current [Abstract]
Other financial assets at fair value through profit or loss	$ 39,289,630	$ 25,844,992
Other Financial Assets at Fair Value [Member]
Current [Abstract]
Other financial assets at fair value through profit or loss	39,289,630	25,844,992
Non Current [Abstract]
Other financial assets at fair value through profit or loss	0	0
Mutual Funds in Local Market [Member]
Current [Abstract]
Other financial assets at fair value through profit or loss	0	152,868
Non Current [Abstract]
Other financial assets at fair value through profit or loss	0	0
Public Debt Bonds [Member]
Current [Abstract]
Other financial assets at fair value through profit or loss	7,162,504	6,432,817
Non Current [Abstract]
Other financial assets at fair value through profit or loss	0	0
Private Debt Bonds with Related Parties [Member]
Current [Abstract]
Other financial assets at fair value through profit or loss	2,570,796	1,388,558
Non Current [Abstract]
Other financial assets at fair value through profit or loss	0	0
Private Debt Bonds [Member]
Current [Abstract]
Other financial assets at fair value through profit or loss	25,808,410	17,870,749
Non Current [Abstract]
Other financial assets at fair value through profit or loss	0	0
Equity Instruments [Member]
Current [Abstract]
Other financial assets at fair value through profit or loss	3,747,920	0
Non Current [Abstract]
Other financial assets at fair value through profit or loss	$ 0	$ 0

XML

DETAIL OF SIGNIFICANT STATEMENT OF FINANCIAL POSITION AND STATEMENT OF COMPREHENSIVE INCOME CAPTIONS, Payroll and Social Security Taxes Payable (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current [Abstract]
Vacation benefit payable	$ 1,296,356	$ 1,186,142
Annual bonus payable	857,151	896,347
Social security taxes payable	471,945	685,123
UT	4,377	6,957
Total	2,629,829	2,774,569
Non Current [Abstract]
Vacation benefit payable	0	0
Annual bonus payable	0	0
Social security taxes payable	0	0
Total	$ 0	$ 0

XML

INVESTMENTS IN ASSOCIATES (Details) - ARS ($) $ / shares in Units, $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Investments in associates [Abstract]
Book value	$ 154,502	$ 64,371
Transporte y Servicios de Gas en Uruguay S.A. [Member]
Investments in associates [Abstract]
Face value (in pesos per share)	$ 1
Amount	$ 196,000
Book value	$ 13,502	19,339
Emprendimientos de Gas del Sur S.A. [Member]
Investments in associates [Abstract]
Face value (in pesos per share)	$ 1
Amount	$ 116,130
Book value	$ 700	1,132
Gas Link S.A. [Member]
Investments in associates [Abstract]
Face value (in pesos per share)	$ 1
Amount	$ 502,962
Book value	$ 140,300	$ 43,900

XML

JOINT ARRANGEMENTS (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Consolidated Statements of financial position [Abstract]
Non Current assets	$ 334,838,690	$ 336,382,939
Current Assets	77,253,535	69,136,977
Total Assets	412,092,225	405,519,916	$ 378,098,311
Non Current Liabilities	123,674,160	131,148,096
Current Liabilities	21,193,776	39,465,333
Total liabilities	144,867,936	170,613,429	183,964,125
Consolidated Statements of comprehensive income [Abstract]
Gross profit	68,483,225	80,476,417	83,225,652
Operating loss	52,448,697	66,391,711	60,689,410
Comprehensive income	$ 32,317,802	40,772,312	9,662,214
UT [Member]
Joint Arrangements [Abstract]
Ownership interest percentage	51.00%
Consolidated Statements of financial position [Abstract]
Non Current assets	$ 0	0
Current Assets	72,020	368,325
Total Assets	72,020	368,325
Non Current Liabilities	0	0
Current Liabilities	278,622	739,043
Total liabilities	278,622	739,043
Consolidated Statements of comprehensive income [Abstract]
Gross profit	27	53	13,415
Operating loss	(7,854)	(15,299)	(3,719)
Net Financial results	141,140	274,931	220,157
Comprehensive income	$ 133,286	$ 259,632	$ 216,438

XML

SHARE OF PROFIT FROM ASSOCIATES (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Profit from associates [Abstract]
Profit from associates	$ 90,138	$ 41,347	$ 62,657
EGS [Member]
Profit from associates [Abstract]
Profit from associates	(432)	(308)	(232)
TGU [Member]
Profit from associates [Abstract]
Profit from associates	(5,837)	(5,770)	(1,418)
Link [Member]
Profit from associates [Abstract]
Profit from associates	$ 96,407	$ 47,425	$ 64,307

XML

PROPERTY, PLANT AND EQUIPMENT, Summary (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	$ 292,534,643
Depreciation	(19,572,669)	$ (18,721,149)	$ (18,115,502)
End of the year	294,479,596	292,534,643
Pipelines [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	120,211,132
End of the year	118,024,752	120,211,132
Compressor Plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	36,187,769
End of the year	35,038,932	36,187,769
Other Plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	59,917
End of the year	56,628	59,917
Stations of Regulation and/or Measurement of Pressure [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	2,013,515
End of the year	1,919,269	2,013,515
Other Technical Installations [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	422,130
End of the year	769,317	422,130
Subtotal Assets Related to Natural Gas Transportation Service [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	158,894,463
End of the year	155,808,898	158,894,463
Non-regulated segment Pipelines [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	40,136,339
End of the year	38,877,501	40,136,339
Non-regulated segment Compressor plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	3,452,116
End of the year	2,654,165	3,452,116
Non-regulated segment Other plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	32,603,651
End of the year	40,504,142	32,603,651
Non-regulated segment Stations of regulation and/or measurement of pressure [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	2,444,636
End of the year	2,337,052	2,444,636
Non-regulated segment other technical installations [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	463,065
End of the year	420,354	463,065
Subtotal Assets Related to Other Services and Production and Commercialization of Liquids [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	79,099,807
End of the year	84,793,214	79,099,807
Lands [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	1,417,568
End of the year	1,417,568	1,417,568
Buildings and Constructions [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	7,717,145
End of the year	7,780,836	7,717,145
Facilities and Features in Building [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	630,365
End of the year	616,197	630,365
Machinery, Equipment and Tools [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	1,892,458
End of the year	1,603,778	1,892,458
UT Machinery, Equipment and Tools [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	0
End of the year	0	0
Computers and Telecommunication Systems [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	5,290,246
End of the year	5,171,596	5,290,246
Vehicles [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	499,504
End of the year	477,099	499,504
Furniture [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	53,415
End of the year	51,709	53,415
Materials [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	15,791,047
End of the year	16,727,794	15,791,047
Line Pack [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	2,022,341
End of the year	2,022,341	2,022,341
Works in Progress [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	19,226,284
End of the year	18,008,566	19,226,284
Cost [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	613,612,215	593,070,489
Additions	21,613,864	20,670,021
Retirements	1,959,370	128,295
Transfers	0	0
End of the year	633,266,709	613,612,215	593,070,489
Cost [Member] | Pipelines [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	265,066,631	263,565,765
Additions	0	0
Retirements	0	586
Transfers	4,361,804	1,501,452
End of the year	269,428,435	265,066,631	263,565,765
Cost [Member] | Compressor Plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	116,840,361	112,497,073
Additions	0	0
Retirements	0	74
Transfers	4,135,224	4,343,362
End of the year	120,975,585	116,840,361	112,497,073
Cost [Member] | Other Plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	106,030	106,030
Additions	0	0
Retirements	0	0
Transfers	0	0
End of the year	106,030	106,030	106,030
Cost [Member] | Stations of Regulation and/or Measurement of Pressure [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	9,502,577	8,933,021
Additions	0	0
Retirements	0	0
Transfers	165,914	569,556
End of the year	9,668,491	9,502,577	8,933,021
Cost [Member] | Other Technical Installations [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	1,964,446	1,701,491
Additions	0	0
Retirements	0	0
Transfers	420,266	262,955
End of the year	2,384,712	1,964,446	1,701,491
Cost [Member] | Subtotal Assets Related to Natural Gas Transportation Service [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	393,480,045	386,803,380
Additions	0	0
Retirements	0	660
Transfers	9,083,208	6,677,325
End of the year	402,563,253	393,480,045	386,803,380
Cost [Member] | Non-regulated segment Pipelines [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	43,520,177	43,383,354
Additions	0	0
Retirements	0	0
Transfers	185,982	136,823
End of the year	43,706,159	43,520,177	43,383,354
Cost [Member] | Non-regulated segment Compressor plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	8,422,007	8,361,565
Additions	0	0
Retirements	0	0
Transfers	72,584	60,442
End of the year	8,494,591	8,422,007	8,361,565
Cost [Member] | Non-regulated segment Other plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	77,586,306	75,790,110
Additions	0	0
Retirements	1,863,128	0
Transfers	10,121,226	1,796,196
End of the year	85,844,404	77,586,306	75,790,110
Cost [Member] | Non-regulated segment Stations of regulation and/or measurement of pressure [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	2,829,148	2,616,454
Additions	0	2,643
Retirements	0	0
Transfers	3,603	210,051
End of the year	2,832,751	2,829,148	2,616,454
Cost [Member] | Non-regulated segment other technical installations [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	1,040,891	1,016,791
Additions	0	0
Retirements	0	0
Transfers	47,379	24,100
End of the year	1,088,270	1,040,891	1,016,791
Cost [Member] | Subtotal Assets Related to Other Services and Production and Commercialization of Liquids [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	133,398,529	131,168,274
Additions	0	2,643
Retirements	1,863,128	0
Transfers	10,430,774	2,227,612
End of the year	141,966,175	133,398,529	131,168,274
Cost [Member] | Lands [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	1,417,568	1,417,568
Additions	0	0
Retirements	0	0
Transfers	0	0
End of the year	1,417,568	1,417,568	1,417,568
Cost [Member] | Buildings and Constructions [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	15,604,574	14,995,664
Additions	0	0
Retirements	0	12
Transfers	372,507	608,922
End of the year	15,977,081	15,604,574	14,995,664
Cost [Member] | Facilities and Features in Building [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	1,157,039	1,055,941
Additions	0	0
Retirements	0	39
Transfers	20,995	101,137
End of the year	1,178,034	1,157,039	1,055,941
Cost [Member] | Machinery, Equipment and Tools [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	5,353,477	4,687,684
Additions	237,299	425,882
Retirements	0	0
Transfers	28,117	239,911
End of the year	5,618,893	5,353,477	4,687,684
Cost [Member] | UT Machinery, Equipment and Tools [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	3,641	3,641
Additions	0	0
Retirements	0	0
Transfers	0	0
End of the year	3,641	3,641	3,641
Cost [Member] | Computers and Telecommunication Systems [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	22,870,210	21,180,182
Additions	0	0
Retirements	0	0
Transfers	1,458,548	1,690,028
End of the year	24,328,758	22,870,210	21,180,182
Cost [Member] | Vehicles [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	2,221,358	2,070,127
Additions	159,632	153,637
Retirements	0	2,406
Transfers	0	0
End of the year	2,380,990	2,221,358	2,070,127
Cost [Member] | Furniture [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	955,440	918,308
Additions	7,472	37,054
Retirements	0	0
Transfers	41	78
End of the year	962,953	955,440	918,308
Cost [Member] | Materials [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	15,791,047	13,940,845
Additions	6,275,734	6,478,730
Retirements	96,242	125,178
Transfers	(5,242,745)	(4,503,350)
End of the year	16,727,794	15,791,047	13,940,845
Cost [Member] | Line Pack [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	2,133,003	2,133,003
Additions	0	0
Retirements	0	0
Transfers	0	0
End of the year	2,133,003	2,133,003	2,133,003
Cost [Member] | Works in Progress [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	19,226,284	12,695,872
Additions	14,933,727	13,572,075
Retirements	0	0
Transfers	(16,151,445)	(7,041,663)
End of the year	18,008,566	19,226,284	12,695,872
Depreciation and Impairment [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(321,077,572)
Retirements	(1,863,128)	(2,459)
Depreciation	(19,572,669)	(18,721,149)
End of the year	(338,787,113)	(321,077,572)
Depreciation and Impairment [Member] | Pipelines [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(144,855,499)
Retirements	0	(341)
Depreciation	$ (6,548,184)	$ (6,427,820)
Depreciation rate %	2.20%	2.20%
End of the year	$ (151,403,683)	$ (144,855,499)
Depreciation and Impairment [Member] | Compressor Plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(80,652,592)
Retirements	0	(70)
Depreciation	(5,284,061)	(4,891,337)
End of the year	(85,936,653)	(80,652,592)
Depreciation and Impairment [Member] | Other Plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(46,113)
Retirements	0	0
Depreciation	$ (3,289)	$ (3,387)
Depreciation rate %	3.30%	3.30%
End of the year	$ (49,402)	$ (46,113)
Depreciation and Impairment [Member] | Stations of Regulation and/or Measurement of Pressure [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(7,489,062)
Retirements	0	0
Depreciation	$ (260,160)	$ (248,260)
Depreciation rate %	4.00%	4.00%
End of the year	$ (7,749,222)	$ (7,489,062)
Depreciation and Impairment [Member] | Other Technical Installations [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(1,542,316)
Retirements	0	0
Depreciation	$ (73,079)	$ (43,172)
Depreciation rate %	6.70%	6.70%
End of the year	$ (1,615,395)	$ (1,542,316)
Depreciation and Impairment [Member] | Subtotal Assets Related to Natural Gas Transportation Service [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(234,585,582)
Retirements	0	(411)
Depreciation	(12,168,773)	(11,613,976)
End of the year	(246,754,355)	(234,585,582)
Depreciation and Impairment [Member] | Non-regulated segment Pipelines [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(3,383,838)
Retirements	0	0
Depreciation	$ (1,444,820)	$ (1,441,686)
Depreciation rate %	2.20%	2.20%
End of the year	$ (4,828,658)	$ (3,383,838)
Depreciation and Impairment [Member] | Non-regulated segment Compressor plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(4,969,891)
Retirements	0	0
Depreciation	(870,535)	(876,704)
End of the year	(5,840,426)	(4,969,891)
Depreciation and Impairment [Member] | Non-regulated segment Other plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(44,982,655)
Retirements	(1,863,128)	0
Depreciation	$ (2,220,735)	$ (1,965,395)
Depreciation rate %	3.30%	3.30%
End of the year	$ (45,340,262)	$ (44,982,655)
Depreciation and Impairment [Member] | Non-regulated segment Stations of regulation and/or measurement of pressure [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(384,512)
Retirements	0	0
Depreciation	$ (111,187)	$ (109,275)
Depreciation rate %	4.00%	4.00%
End of the year	$ (495,699)	$ (384,512)
Depreciation and Impairment [Member] | Non-regulated segment other technical installations [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(577,826)
Retirements	0	0
Depreciation	$ (90,090)	$ (92,433)
Depreciation rate %	6.70%	6.70%
End of the year	$ (667,916)	$ (577,826)
Depreciation and Impairment [Member] | Subtotal Assets Related to Other Services and Production and Commercialization of Liquids [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(54,298,722)
Retirements	(1,863,128)	0
Depreciation	(4,737,367)	(4,485,493)
End of the year	(57,172,961)	(54,298,722)
Depreciation and Impairment [Member] | Lands [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	0
Retirements	0	0
Depreciation	$ 0	$ 0
Depreciation rate %	0.00%	0.00%
End of the year	$ 0	$ 0
Depreciation and Impairment [Member] | Buildings and Constructions [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(7,887,429)
Retirements	0	(10)
Depreciation	$ (308,816)	$ (298,961)
Depreciation rate %	2.00%	2.00%
End of the year	$ (8,196,245)	$ (7,887,429)
Depreciation and Impairment [Member] | Facilities and Features in Building [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(526,674)
Retirements	0	(37)
Depreciation	$ (35,163)	$ (30,742)
Depreciation rate %	4.00%	4.00%
End of the year	$ (561,837)	$ (526,674)
Depreciation and Impairment [Member] | Machinery, Equipment and Tools [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(3,461,019)
Retirements	0	0
Depreciation	(554,096)	(461,946)
End of the year	(4,015,115)	(3,461,019)
Depreciation and Impairment [Member] | UT Machinery, Equipment and Tools [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(3,641)
Retirements	0	0
Depreciation	0	0
End of the year	(3,641)	(3,641)
Depreciation and Impairment [Member] | Computers and Telecommunication Systems [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(17,579,964)
Retirements	0	0
Depreciation	(1,577,198)	(1,647,368)
End of the year	(19,157,162)	(17,579,964)
Depreciation and Impairment [Member] | Vehicles [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(1,721,854)
Retirements	0	(2,001)
Depreciation	$ (182,037)	$ (176,385)
Depreciation rate %	20.00%	20.00%
End of the year	$ (1,903,891)	$ (1,721,854)
Depreciation and Impairment [Member] | Furniture [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(902,025)
Retirements	0	0
Depreciation	$ (9,219)	$ (6,278)
Depreciation rate %	10.00%	10.00%
End of the year	$ (911,244)	$ (902,025)
Depreciation and Impairment [Member] | Materials [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	0
Retirements	0	0
Depreciation	$ 0	$ 0
Depreciation rate %	0.00%	0.00%
End of the year	$ 0	$ 0
Depreciation and Impairment [Member] | Line Pack [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	(110,662)
Retirements	0	0
Depreciation	$ 0	$ 0
Depreciation rate %	0.00%	0.00%
End of the year	$ (110,662)	$ (110,662)
Depreciation and Impairment [Member] | Works in Progress [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year	0
Retirements	0	0
Depreciation	$ 0	$ 0
Depreciation rate %	0.00%	0.00%
End of the year	$ 0	$ 0
Depreciation [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(302,358,882)
End of the year			(302,358,882)
Depreciation [Member] | Pipelines [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(138,428,020)
End of the year			(138,428,020)
Depreciation [Member] | Compressor Plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ (75,761,325)
End of the year			(75,761,325)
Depreciation [Member] | Compressor Plants [Member] | Bottom of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	3.30%	3.30%
Depreciation [Member] | Compressor Plants [Member] | Top of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	25.00%	25.00%
Depreciation [Member] | Other Plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ (42,726)
End of the year			(42,726)
Depreciation [Member] | Stations of Regulation and/or Measurement of Pressure [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(7,240,802)
End of the year			(7,240,802)
Depreciation [Member] | Other Technical Installations [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(1,499,144)
End of the year			(1,499,144)
Depreciation [Member] | Subtotal Assets Related to Natural Gas Transportation Service [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(222,972,017)
End of the year			(222,972,017)
Depreciation [Member] | Non-regulated segment Pipelines [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(1,942,152)
End of the year			(1,942,152)
Depreciation [Member] | Non-regulated segment Compressor plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ (4,093,187)
End of the year			(4,093,187)
Depreciation [Member] | Non-regulated segment Compressor plants [Member] | Bottom of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	3.30%	3.30%
Depreciation [Member] | Non-regulated segment Compressor plants [Member] | Top of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	25.00%	25.00%
Depreciation [Member] | Non-regulated segment Other plants [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ (43,017,260)
End of the year			(43,017,260)
Depreciation [Member] | Non-regulated segment Stations of regulation and/or measurement of pressure [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(275,237)
End of the year			(275,237)
Depreciation [Member] | Non-regulated segment other technical installations [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(485,393)
End of the year			(485,393)
Depreciation [Member] | Subtotal Assets Related to Other Services and Production and Commercialization of Liquids [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(49,813,229)
End of the year			(49,813,229)
Depreciation [Member] | Lands [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		0
End of the year			0
Depreciation [Member] | Buildings and Constructions [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(7,588,478)
End of the year			(7,588,478)
Depreciation [Member] | Facilities and Features in Building [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(495,969)
End of the year			(495,969)
Depreciation [Member] | Machinery, Equipment and Tools [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ (2,999,073)
End of the year			(2,999,073)
Depreciation [Member] | Machinery, Equipment and Tools [Member] | Bottom of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	6.70%	6.70%
Depreciation [Member] | Machinery, Equipment and Tools [Member] | Top of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	10.00%	10.00%
Depreciation [Member] | UT Machinery, Equipment and Tools [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ (3,641)
End of the year			(3,641)
Depreciation [Member] | UT Machinery, Equipment and Tools [Member] | Bottom of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	6.70%	6.70%
Depreciation [Member] | UT Machinery, Equipment and Tools [Member] | Top of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	10.00%	10.00%
Depreciation [Member] | Computers and Telecommunication Systems [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ (15,932,596)
End of the year			(15,932,596)
Depreciation [Member] | Computers and Telecommunication Systems [Member] | Bottom of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	6.70%	6.70%
Depreciation [Member] | Computers and Telecommunication Systems [Member] | Top of Range [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Depreciation rate %	20.00%	20.00%
Depreciation [Member] | Vehicles [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ (1,547,470)
End of the year			(1,547,470)
Depreciation [Member] | Furniture [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(895,747)
End of the year			(895,747)
Depreciation [Member] | Materials [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		0
End of the year			0
Depreciation [Member] | Line Pack [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		(110,662)
End of the year			(110,662)
Depreciation [Member] | Works in Progress [Member]
Reconciliation of changes in property, plant and equipment [Abstract]
Beginning of the year		$ 0
End of the year			$ 0

XML

PROPERTY, PLANT AND EQUIPMENT, Composition of Net Value of Property, Plant and Equipment (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Resulting net value of property, plant and equipment [Abstract]
Property, plant and equipment	$ 294,479,596	$ 292,534,643
Cost [Member]
Resulting net value of property, plant and equipment [Abstract]
Property, plant and equipment	633,266,709	613,612,215	$ 593,070,489
Accumulated Depreciation [Member]
Resulting net value of property, plant and equipment [Abstract]
Property, plant and equipment	$ (338,787,113)	$ (321,077,572)

XML

PROPERTY, PLANT AND EQUIPMENT, Right-of-use Assets (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Other Services and Production and Commercialization of Liquids Segments [Abstract]
Right-of-use assets	$ 3,716,014	$ 4,729,471
Book value Variation of Rights-of Use [Abstract]
Depreciation, right-of-use assets	(1,013,457)	(1,013,459)
Other Plants [Member]
Other Services and Production and Commercialization of Liquids Segments [Abstract]
Right-of-use assets	986,979	1,256,155
Book value Variation of Rights-of Use [Abstract]
Depreciation, right-of-use assets	(269,176)	(269,177)
Compressor Plants [Member]
Other Services and Production and Commercialization of Liquids Segments [Abstract]
Right-of-use assets	2,450,404	3,118,695
Book value Variation of Rights-of Use [Abstract]
Depreciation, right-of-use assets	(668,291)	(668,293)
Other Technical Installations [Member]
Other Services and Production and Commercialization of Liquids Segments [Abstract]
Right-of-use assets	278,631	354,621
Book value Variation of Rights-of Use [Abstract]
Depreciation, right-of-use assets	$ (75,990)	$ (75,989)

XML

LOANS, Short-term and Long-term Loans (Details) - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022		Dec. 31, 2021
Current Loans [Abstract]
Total Current loans		$ 3,919,929		$ 2,299,738
Non Current Loans [Abstract]
Total non current loans		90,694,136		100,121,274
Total	[2]	94,614,065	[1]	102,421,012
Notes repurchase		5,257,400		4,484,852
Issuance expenses		30,105		102,623
2018 Notes [Member]
Current Loans [Abstract]
Total Current loans		937,379		1,075,060
Non Current Loans [Abstract]
Total non current loans		83,292,496		95,458,303
Total		84,229,875
Bank Loans [Member]
Current Loans [Abstract]
Total Current loans		1,440,989		0
Non Current Loans [Abstract]
Total non current loans		4,303,571		0
Total		5,744,560
Other Financial Liabilities [Member]
Current Loans [Abstract]
Total Current loans		377,415		0
Non Current Loans [Abstract]
Total		377,415
Financial Leases [Member]
Current Loans [Abstract]
Total Current loans		1,164,146		1,224,678
Non Current Loans [Abstract]
Total non current loans		3,098,069		$ 4,662,971
Total		$ 4,262,215

[1] As of December 31, 2022 and 2021, it is net of Notes repurchase of Ps 5,257,400 and Ps. 4,484,852, respectively.

[2] Net of issuance expenses of Ps. 30,105 and Ps. 102,623 as of December 31, 2022 and 2021, respectively.

XML

LOANS, Activity of Loans (Details) - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022		Dec. 31, 2021	Dec. 31, 2020
Activity of Loans [Abstract]
Beginning balance	[1]	$ 102,421,012
Proceeds from loans		6,164,853		$ 0	$ 0
Acquisition of notes result		(1,030,169)		(806,841)	1,174,202
Payment of loans		(86,187)		0	(3,981,411)
Ending balance	[1]	94,614,065	[2]	102,421,012
Amount cancelled through offsetting of principal payments maintained with creditor		901,526		1,163,922
Amount cancelled through offsetting of interest paid maintained with creditor		365,566		614,146
Leases Liabilities [Member]
Activity of Loans [Abstract]
Beginning balance		5,887,649		8,505,178
Inflation adjustment restatement		(4,769,942)		(3,164,211)
Accrued interest		382,649		568,315
Effect of foreign exchange effect		4,005,769		1,730,223
VAT unpaid installments		23,182		26,212
Proceeds from loans		0		0
Acquisition of notes result		0		0
Payment of loans		(901,526)		(1,163,922)
Acquisition of notes	[3]	0		0
Interest paid	[3]	(365,566)		(614,146)
Ending balance		4,262,215		5,887,649	8,505,178
Other Payables [Member]
Activity of Loans [Abstract]
Beginning balance		96,533,363		120,481,460
Inflation adjustment restatement		(58,645,278)		(44,998,198)
Accrued interest		5,875,804		7,321,812
Effect of foreign exchange effect		47,656,779		22,095,210
VAT unpaid installments		0		0
Proceeds from loans		6,164,853		0
Acquisition of notes result		1,030,169		806,841
Payment of loans		(86,187)		0
Acquisition of notes	[3]	(2,452,516)		(1,869,224)
Interest paid	[3]	(5,725,137)		(7,304,538)
Ending balance		$ 90,351,850		$ 96,533,363	$ 120,481,460

[1] Net of issuance expenses of Ps. 30,105 and Ps. 102,623 as of December 31, 2022 and 2021, respectively.

[2] As of December 31, 2022 and 2021, it is net of Notes repurchase of Ps 5,257,400 and Ps. 4,484,852, respectively.

[3] For the years ended on December 31, 2022 and 2021, Ps. 365,566 and Ps. 614,146, respectively, were cancelled through the offseting of debit balances maintained with the creditor (Pampa Energía).

XML

LOANS, Maturities of Current and Non-current Loans (Details) - ARS ($) $ in Thousands		Dec. 31, 2022		Dec. 31, 2021
Maturities of current and non-current loans [Abstract]
Loans	[2]	$ 94,614,065	[1]	$ 102,421,012
Due [Member]
Maturities of current and non-current loans [Abstract]
Loans		133,549
From 1/01/2023 to 12/31/2023
Maturities of current and non-current loans [Abstract]
Loans		3,786,380
From 1/01/2024 to 12/31/2024 [Member]
Maturities of current and non-current loans [Abstract]
Loans		5,420,596
From 01/01/2025 to 12/31/2025 [Member]
Maturities of current and non-current loans [Abstract]
Loans		84,503,312
From 1/01/2026 to 12/31/2026 [Member]
Maturities of current and non-current loans [Abstract]
Loans		770,228
From 1/01/2027 onwards [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
2018 Notes [Member]
Maturities of current and non-current loans [Abstract]
Loans		84,229,875
2018 Notes [Member] | Due [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
2018 Notes [Member] | From 1/01/2023 to 12/31/2023
Maturities of current and non-current loans [Abstract]
Loans		937,379
2018 Notes [Member] | From 1/01/2024 to 12/31/2024 [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
2018 Notes [Member] | From 01/01/2025 to 12/31/2025 [Member]
Maturities of current and non-current loans [Abstract]
Loans		83,292,496
2018 Notes [Member] | From 1/01/2026 to 12/31/2026 [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
2018 Notes [Member] | From 1/01/2027 onwards [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Financial Leasing [Member]
Maturities of current and non-current loans [Abstract]
Loans		4,262,215
Financial Leasing [Member] | Due [Member]
Maturities of current and non-current loans [Abstract]
Loans		133,549
Financial Leasing [Member] | From 1/01/2023 to 12/31/2023
Maturities of current and non-current loans [Abstract]
Loans		1,030,597
Financial Leasing [Member] | From 1/01/2024 to 12/31/2024 [Member]
Maturities of current and non-current loans [Abstract]
Loans		1,117,025
Financial Leasing [Member] | From 01/01/2025 to 12/31/2025 [Member]
Maturities of current and non-current loans [Abstract]
Loans		1,210,816
Financial Leasing [Member] | From 1/01/2026 to 12/31/2026 [Member]
Maturities of current and non-current loans [Abstract]
Loans		770,228
Financial Leasing [Member] | From 1/01/2027 onwards [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Other Financial Liabilities [Member]
Maturities of current and non-current loans [Abstract]
Loans		377,415
Other Financial Liabilities [Member] | Due [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Other Financial Liabilities [Member] | From 1/01/2023 to 12/31/2023
Maturities of current and non-current loans [Abstract]
Loans		377,415
Other Financial Liabilities [Member] | From 1/01/2024 to 12/31/2024 [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Other Financial Liabilities [Member] | From 01/01/2025 to 12/31/2025 [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Other Financial Liabilities [Member] | From 1/01/2026 to 12/31/2026 [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Other Financial Liabilities [Member] | From 1/01/2027 onwards [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Bank Loans [Member]
Maturities of current and non-current loans [Abstract]
Loans		5,744,560
Bank Loans [Member] | Due [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Bank Loans [Member] | From 1/01/2023 to 12/31/2023
Maturities of current and non-current loans [Abstract]
Loans		1,440,989
Bank Loans [Member] | From 1/01/2024 to 12/31/2024 [Member]
Maturities of current and non-current loans [Abstract]
Loans		4,303,571
Bank Loans [Member] | From 01/01/2025 to 12/31/2025 [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Bank Loans [Member] | From 1/01/2026 to 12/31/2026 [Member]
Maturities of current and non-current loans [Abstract]
Loans		0
Bank Loans [Member] | From 1/01/2027 onwards [Member]
Maturities of current and non-current loans [Abstract]
Loans		$ 0

[1] As of December 31, 2022 and 2021, it is net of Notes repurchase of Ps 5,257,400 and Ps. 4,484,852, respectively.

[2] Net of issuance expenses of Ps. 30,105 and Ps. 102,623 as of December 31, 2022 and 2021, respectively.

XML

LOANS, Maturities of Finance Leases and Future Minimum Lease Payments (Details) $ in Thousands	Dec. 31, 2022 ARS ($)
Disclosure of maturities of finance leases and future minimum lease payments [Abstract]
Total minimum future payments	$ 4,901,101
Future financial charges on financial leases	(638,886)
Book value financial leases	4,262,215
As of 12/31/2023 [Member]
Disclosure of maturities of finance leases and future minimum lease payments [Abstract]
Total minimum future payments	1,458,705
From 1/01/2024 to 12/31/2024 [Member]
Disclosure of maturities of finance leases and future minimum lease payments [Abstract]
Total minimum future payments	1,325,334
From 01/01/2025 to 12/31/2025 [Member]
Disclosure of maturities of finance leases and future minimum lease payments [Abstract]
Total minimum future payments	1,325,334
From 1/01/2026 to 12/31/2026 [Member]
Disclosure of maturities of finance leases and future minimum lease payments [Abstract]
Total minimum future payments	791,728
From 1/01/2027 onwards [Member]
Disclosure of maturities of finance leases and future minimum lease payments [Abstract]
Total minimum future payments	$ 0

XML

LOANS, 2018 Notes (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2022 ARS ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 ARS ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 ARS ($)	Dec. 31, 2018 USD ($)
Issuance of notes [Abstract]
Cancellation and redemption of note	$ 2,452,516		$ 1,869,224		$ 2,939,684
Acquisition of notes result	$ (1,030,169)		(806,841)		$ 1,174,202
2014 Note [Member]
Issuance of notes [Abstract]
Repurchase of note		$ 86,511,165
Cancellation and redemption of note		120,786,581
2014 Note [Member] | Top of Range [Member]
Issuance of notes [Abstract]
Maximum principal amount		400,000,000
2018 Note [Member]
Issuance of notes [Abstract]
Principal amount		$ 500,000,000
Interest rate		6.75%
Issuance price		99.725%
Frequency of interest payment	Semiannual, payable on May 2 and November 2 of each year	Semiannual, payable on May 2 and November 2 of each year
Guarantor	None	None
Percentage of cash flows discounted at an effective rate		7.088%
2018 Note [Member] | May 2, 2025 [Member]
Issuance of notes [Abstract]
Percentage of original principal amount		100.00%
2018 Note [Member] | Top of Range [Member]
Issuance of notes [Abstract]
Maximum principal amount		$ 1,200,000,000				$ 700,000,000
Marketable Debt [Member]
Issuance of notes [Abstract]
Repurchase of note	$ 2,452,516	$ 29,700,000	1,869,224	$ 4,800,000
Acquisition of notes result	$ (1,030,169)		$ (806,841)

XML

LOANS, Other Financial Liabilities (Details) € in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2022 USD ($)	Dec. 31, 2022 EUR (€)
Between May and September 2023 [Member]
Other financial liabilities [Abstract]
Other financial liabilities	$ 1,797
Expiration date	Between May and September 2023
Between May and September 2023 [Member] | Bottom of Range [Member]
Other financial liabilities [Abstract]
Interest rate	5.75%	5.75%
Between May and September 2023 [Member] | Top of Range [Member]
Other financial liabilities [Abstract]
Interest rate	7.75%	7.75%
April / May 2023 [Member]
Other financial liabilities [Abstract]
Other financial liabilities | €		€ 284
Expiration date	April / May 2023
April / May 2023 [Member] | Bottom of Range [Member]
Other financial liabilities [Abstract]
Interest rate	3.05%	3.05%
April / May 2023 [Member] | Top of Range [Member]
Other financial liabilities [Abstract]
Interest rate	3.85%	3.85%
August 2023 [Member]
Other financial liabilities [Abstract]
Other financial liabilities	$ 8,000
Interest rate	4.30%	4.30%
Expiration date	August 2023

XML

LOANS, Bank Loans (Details) - Bank Loans [Member] - Telcosur S.A. [Member] $ in Millions	Mar. 31, 2022 USD ($)
Bank loans [Abstract]
Principal amount	$ 24
Interest rate	1.50%
Amortizacion date	Jan. 25, 2024
Interest payment frequency	To the expiration
Guarantee	Fixed term in foreign currency	[1]

[1] Included as “Non-current financial assets measured at amortised cost”.

XML

LOANS, Covenants and Financial leasing (Details)	12 Months Ended
	Dec. 31, 2022 USD ($) Installment
Financial Leasing [Abstract]
Number of monthly installments | Installment	119
Bottom of Range [Member]
Covenants [Abstract]
Consolidated coverage ratio	2
Top of Range [Member]
Covenants [Abstract]
Consolidated debt ratio	3.75
Pampa Energia [Member]
Financial Leasing [Abstract]
Monthly payment amount | $	$ 623,457
Period of option to purchase financial leasing agreement for same amount	120 months

XML

INCOME TAX AND DEFERRED TAX, Summary (Details) $ in Thousands			12 Months Ended
	Jun. 16, 2021 ARS ($) Segment	Jan. 01, 2021	Dec. 31, 2022 ARS ($) Installment	Dec. 31, 2021 ARS ($)	Dec. 31, 2020 ARS ($)	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Reduction in the applicable rate [Abstract]
Income tax rate			35.00%	35.00%	30.00%	30.00%	30.00%	35.00%
Additional tax depending on dividends distributed at the rate of 30%			7.00%
Additional tax depending on dividends distributed at the rate of 25%			13.00%
Number of segments for accumulated net taxable income | Segment	3
Accumulated pre-tax income			$ 17,282,634	$ 22,954,106	$ 6,783,682
Tax rate on dividends distributions to foreign individuals and beneficiaries			7.00%
Tax Revaluation [Abstract]
Number of consecutive monthly installments | Installment			5
Adjustments of deducted taxed		100.00%
Current advances from customers			$ 3,367,653
Segment 1 [Member]
Reduction in the applicable rate [Abstract]
Income tax rate	25.00%
Segment 2 [Member]
Reduction in the applicable rate [Abstract]
Income tax rate	30.00%
Segment 3 [Member]
Reduction in the applicable rate [Abstract]
Income tax rate	35.00%
Bottom of Range [Member] | Segment 2 [Member]
Reduction in the applicable rate [Abstract]
Accumulated pre-tax income	$ 5,000
Bottom of Range [Member] | Segment 3 [Member]
Reduction in the applicable rate [Abstract]
Accumulated pre-tax income	50,000
Top of Range [Member] | Segment 1 [Member]
Reduction in the applicable rate [Abstract]
Accumulated pre-tax income	5,000
Top of Range [Member] | Segment 2 [Member]
Reduction in the applicable rate [Abstract]
Accumulated pre-tax income	$ 50,000
2019 [Member]
Reduction in the applicable rate [Abstract]
Income tax rate			30.00%
2020 and Onwards [Member]
Reduction in the applicable rate [Abstract]
Income tax rate			25.00%
2021 and Onwards [Member]
Reduction in the applicable rate [Abstract]
Income tax rate			25.00%

XML

INCOME TAX AND DEFERRED TAX, Income Tax (Expense)/Gain (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
INCOME TAX AND DEFERRED TAX [Abstract]
Current income tax	$ (15,857,624)	$ (26,694,111)	$ (10,113,083)
Deferred income tax	(1,203,529)	1,883,262	(2,836,978)
Total income tax	$ (17,061,153)	$ (24,810,849)	$ (12,950,061)

XML

INCOME TAX AND DEFERRED TAX, Analysis of Deferred Tax Assets and Liabilities (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Deferred tax assets [Abstract]
Deferred tax assets to be recovered after more than 12 months	$ 3,626,709	$ 7,846,119
Deferred tax assets to be recovered after less than 12 months	1,412,828	1,247,816
Deferred tax liabilities [Abstract]
Deferred tax liabilities taxable after more than 12 months	(25,574,208)	(28,787,450)
Deferred tax liabilities taxable after less than 12 months	(686,246)	(323,873)
Deferred tax liabilities, net	$ (21,220,917)	$ (20,017,388)

XML

INCOME TAX AND DEFERRED TAX, Component of Net Deferred Tax Assets and Liabilities (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	$ (20,017,388)
Deferred tax assets (liability), end of year	(21,220,917)	$ (20,017,388)
Deferred tax asset not recognized		364,769
Foreign Exchange Gains (Losses) [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Loss carryforward on exchange differences of financial instruments		3,662,207
Deferred Tax Assets [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	9,093,935	4,771,040
Charge in results	(4,054,398)	4,322,895
Deferred tax assets (liability), end of year	5,039,537	9,093,935
Deferred Tax Assets [Member] | Other Receivables [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	0	39,744
Charge in results	0	(39,744)
Deferred tax assets (liability), end of year	0	0
Deferred Tax Assets [Member] | Account Receivables Discounted Value [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	1,776	1,891
Charge in results	(1,776)	(115)
Deferred tax assets (liability), end of year	0	1,776
Deferred Tax Assets [Member] | Provisions for Legal Claims and Other Provisions [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	1,007,982	656,071
Charge in results	(366,049)	351,911
Deferred tax assets (liability), end of year	641,933	1,007,982
Deferred Tax Assets [Member] | Financial Leases [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	2,007,846	2,140,878
Charge in results	(562,847)	(133,032)
Deferred tax assets (liability), end of year	1,444,999	2,007,846
Deferred Tax Assets [Member] | Contract Liabilities [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	2,749,665	1,880,469
Charge in results	6,764	869,196
Deferred tax assets (liability), end of year	2,756,429	2,749,665
Deferred Tax Assets [Member] | Tax Loss Carryforward [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	3,297,438	2,776
Charge in results	(3,297,438)	3,294,662
Deferred tax assets (liability), end of year	0	3,297,438
Deferred Tax Assets [Member] | Tax Inflation Adjustment [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	29,228	49,211
Charge in results	(16,667)	(19,983)
Deferred tax assets (liability), end of year	12,561	29,228
Deferred Tax Assets [Member] | Financial Assets at Fair Value Through Profit or Loss [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	0	0
Charge in results	183,615	0
Deferred tax assets (liability), end of year	183,615	0
Deferred Tax Liabilities [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	(29,111,323)	(26,671,690)
Charge in results	2,850,869	(2,439,633)
Deferred tax assets (liability), end of year	(26,260,454)	(29,111,323)
Deferred Tax Liabilities [Member] | Other Receivables [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	(5,226)	0
Charge in results	(114,164)	(5,226)
Deferred tax assets (liability), end of year	(119,390)	(5,226)
Deferred Tax Liabilities [Member] | Tax Inflation Adjustment [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	(7,124,779)	(10,549,673)
Charge in results	4,492,529	3,424,894
Deferred tax assets (liability), end of year	(2,632,250)	(7,124,779)
Deferred Tax Liabilities [Member] | Loans [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	(163,412)	(58,641)
Charge in results	23,424	(104,771)
Deferred tax assets (liability), end of year	(139,988)	(163,412)
Deferred Tax Liabilities [Member] | Property, Plant and Equipment [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	(21,405,145)	(15,369,172)
Charge in results	(1,417,423)	(6,035,973)
Deferred tax assets (liability), end of year	(22,822,568)	(21,405,145)
Deferred Tax Liabilities [Member] | Cash and Cash Equivalents [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	(33,618)	(3,047)
Charge in results	(392,781)	(30,571)
Deferred tax assets (liability), end of year	(426,399)	(33,618)
Deferred Tax Liabilities [Member] | Inventories [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	(126,843)	(98,569)
Charge in results	6,984	(28,274)
Deferred tax assets (liability), end of year	(119,859)	(126,843)
Deferred Tax Liabilities [Member] | Financial Assets at Amortized Cost [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	0	(592,588)
Charge in results	0	592,588
Deferred tax assets (liability), end of year	0	0
Deferred Tax Liabilities [Member] | Other Liabilities [Member]
Components of Net Deferred Tax Assets and Liabilities [abstract]
Deferred tax assets (liability), beginning of year	(252,300)	0
Charge in results	252,300	(252,300)
Deferred tax assets (liability), end of year	$ 0	$ (252,300)

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INCOME TAX AND DEFERRED TAX, Effective Income Tax Rate Reconciliation (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Effective Income Tax Rate Reconciliation [abstract]
Pre-tax income	$ 49,378,955	$ 65,583,161	$ 22,612,275
Statutory income tax rate	35.00%	35.00%	30.00%	30.00%	30.00%	35.00%
Pre-tax income at statutory income tax rate	$ (17,282,634)	$ (22,954,106)	$ (6,783,682)
Tax Effects Due to [Abstract]
Restatement by inflation	2,968,108	11,276,529	6,159,982
Tax loss variation	0	3,297,438	0
Unrecognized tax loss carryforward	0	0	(5,988,032)
Adjustment affidavit previous year	(82,082)	(131,655)	(26,677)
Tax inflation adjustment	(2,717,831)	(7,678,237)	(8,159,343)
Variation of tax rate	0	(7,955,019)	0
Others	53,286	(665,799)	1,847,691
Total income tax	$ (17,061,153)	$ (24,810,849)	$ (12,950,061)

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PROVISIONS (Details) - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022		Dec. 31, 2021
Legal Claims and Others [Member]
Reconciliation of changes in other provisions [abstract]
Beginning balance		$ 2,524,233		$ 2,530,671
Inflation adjustment restatement		(1,445,722)		(1,023,648)
Additions		804,831	[1]	1,036,496	[2]
Uses		(20,248)		(9,751)
Decreases	[3]	(29,000)		(9,535)
Ending balance		1,834,094		2,524,233
Other Operating Expenses [Member]
Reconciliation of changes in other provisions [abstract]
Additions		356,890		557,718
Financial Expenses [Member]
Reconciliation of changes in other provisions [abstract]
Additions		$ 447,941		$ 478,778

[1] Ps. 356,890 are included in “Other operating expenses” and Ps. 447,941 in “Financial expenses”.

[2] Ps. 557,718 are included in “Other operating expenses” and Ps. 478,778 in “Financial expenses”.

[3] The total are included in “Other operating expenses”.

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FINANCIAL RISK MANAGEMENT, Foreign Exchange Risk (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Foreign exchange risk [Abstract]
Number of working days to settle commitment in foreign exchange market	5 days
Percentage of principal amount maturing in maximum period	40.00%
Average life for refinanced new external indebtedness	2 years
Pretax loss	$ 49,378,955	$ 65,583,161	$ 22,612,275
Foreign Exchange Risk [Member]
Foreign exchange risk [Abstract]
Percentage of funds denominated in US dollars to mitigate foreign exchange risk	89.00%
Percentage appreciation (depreciation) of US Dollar against Argentine Peso	10.00%
Pretax loss	$ (1,975,626)	$ (3,962,154)
U.S. Dollars [Member] | Liquids Production and Commercialization [Member] | Foreign Exchange Risk [Member]
Foreign exchange risk [Abstract]
Percentage of revenue	87.00%	87.00%	87.00%
Argentine Pesos [Member] | Liquids Production and Commercialization [Member] | Foreign Exchange Risk [Member]
Foreign exchange risk [Abstract]
Percentage of revenue	35.00%	37.00%	50.00%
Percentage of operating cost	83.00%	81.00%	80.00%

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FINANCIAL RISK MANAGEMENT, Interest Rate Risk (Details) $ in Thousands		12 Months Ended
		Dec. 31, 2022 ARS ($)	Dec. 31, 2021 ARS ($)
Financial Assets and Financial Liabilities [Abstract]
Financial assets		$ 103,756,309	$ 102,057,859
Financial liabilities		107,579,080	117,223,016
Interest Rate Risk [Member]
Financial Assets and Financial Liabilities [Abstract]
Financial assets		41,989,502	77,981,989
Financial liabilities	[1]	$ 86,048,279	96,533,363
Decrease in variable rate basis		0.0100
Interest Rate Risk [Member] | Fixed Interest Rate [Member]
Financial Assets and Financial Liabilities [Abstract]
Financial assets		$ 39,323,688	43,932,998
Financial liabilities	[1]	86,048,279	96,533,363
Interest Rate Risk [Member] | Variable Interest Rate [Member]
Financial Assets and Financial Liabilities [Abstract]
Financial assets		2,665,814	34,048,991
Financial liabilities	[1]	$ 0	$ 0

[1] Includes 2018 Notes. For further information see Note 13 to the Consolidated Financial Statements.

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FINANCIAL RISK MANAGEMENT, Commodity Price Risk (Details) - Commodity Price Risk [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2022 ARS ($) $ / Ton	Dec. 31, 2021 ARS ($) $ / Ton	Dec. 31, 2020 ARS ($) $ / Ton
Commodity Rate Risk [Abstract]
Percentage decrease in price of Liquids due to COVID	30.00%
Increase (decrease) in international price of LPG and natural gasoline | $ / Ton	50	50	50
Liquids Production and Commercialization [Member]
Commodity Rate Risk [Abstract]
Decrease in net comprehensive income due to commodity risk | $	$ 3,207,213	$ 4,378,871	$ 5,935,956

XML

FINANCIAL RISK MANAGEMENT, Credit Risk, Provision for Losses (Details)	Dec. 31, 2022
Natural Gas Transportation Segment [Member] | 90 Days [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	0.50%
Natural Gas Transportation Segment [Member] | 120 Days [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	5.00%
Natural Gas Transportation Segment [Member] | 180 Days [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	10.00%
Natural Gas Transportation Segment [Member] | +240 Days [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	100.00%
Natural Gas Transportation Segment [Member] | Non-Due [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	0.00%
Other Segments [Member] | 90 Days [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	0.25%
Other Segments [Member] | 120 Days [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	2.00%
Other Segments [Member] | 180 Days [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	5.00%
Other Segments [Member] | +240 Days [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	100.00%
Other Segments [Member] | Non-Due [Member]
Provision for Losses Trade Receivables [Abstract]
Provision for losses ratio	0.00%

XML

FINANCIAL RISK MANAGEMENT, Credit Risk, Trade and Other Receivables (Details) - ARS ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022		Dec. 31, 2021		Dec. 31, 2020
Trade and Other Receivables, Current and Noncurrent [Abstract]
Current trade receivables	$ 17,071,816		$ 20,951,996
Allowances for doubtful accounts	(132,521)	[1]	(258,142)	[1]	$ (389,643)
Total	16,939,295		20,693,854
Credits for subsidies	3,768,159		2,427,450
Trade and other receivables [Abstract]
Revenues	164,524,789		173,319,821		164,275,443
Cash and financial placements [Abstract]
Exchange losses on financial instruments	(1,613,742)		(3,694,962)		(23,456,438)
Natural Gas Transportation [Member]
Trade and other receivables [Abstract]
Revenues			47,729,944
Natural Gas Transportation [Member] | MetroGas [Member]
Trade and other receivables [Abstract]
Revenues	10,355,756		11,821,815		17,330,099
Trade receivables	768,193		2,809,625
Natural Gas Transportation [Member] | Camuzzi Gas Pampeana S.A. [Member]
Trade and other receivables [Abstract]
Revenues	7,668,510		8,708,964		12,813,975
Trade receivables	567,671		681,780
Natural Gas Transportation [Member] | Naturgy Argentina [Member]
Trade and other receivables [Abstract]
Revenues	6,286,027		7,051,418		10,358,472
Trade receivables	483,552		586,216
Natural Gas Transportation [Member] | CAMMESA [Member]
Trade and other receivables [Abstract]
Revenues	3,795,168		5,400,240		6,887,604
Trade receivables	1,380,126		1,194,018
Natural Gas Transportation [Member] | Pampa Energia [Member]
Trade and other receivables [Abstract]
Revenues	1,471,413		1,666,555		2,473,548
Trade receivables	111,450		637,807
Natural Gas Transportation [Member] | Camuzzi Gas del Sur S.A. [Member]
Trade and other receivables [Abstract]
Revenues	1,816,770		2,012,977		3,066,612
Trade receivables	118,208		294,958
Liquids Production and Commercialization [Member] | Pampa Energia [Member]
Trade and other receivables [Abstract]
Revenues	3,583,230		4,996,215		0
Trade receivables	281,774		659,046
Liquids Production and Commercialization [Member] | PBB Polisur [Member]
Trade and other receivables [Abstract]
Revenues	25,589,826		26,657,675		27,355,042
Trade receivables	3,569,289		2,778,544
Liquids Production and Commercialization [Member] | Petredec [Member]
Trade and other receivables [Abstract]
Revenues	0		0		2,032,373
Trade receivables	0		0
Liquids Production and Commercialization [Member] | Geogas Trading S.A. [Member]
Trade and other receivables [Abstract]
Revenues	3,668,557		7,402,250		845,467
Trade receivables	0		5,235,421
Liquids Production and Commercialization [Member] | Italgas S.A. [Member]
Trade and other receivables [Abstract]
Revenues	0		295,028		1,165,237
Trade receivables	0		0
Liquids Production and Commercialization [Member] | YPF [Member]
Trade and other receivables [Abstract]
Revenues	2,598,667		3,700,237		2,862,061
Trade receivables	160,887		66,832
Liquids Production and Commercialization [Member] | Petrobras Global Trading BV [Member]
Trade and other receivables [Abstract]
Revenues	280,416		10,953,530		13,263,199
Trade receivables	0		0
Liquids Production and Commercialization [Member] | Trafigura Beheer [Member]
Trade and other receivables [Abstract]
Revenues	15,968,772		13,490,509		0
Trade receivables	898,027		1,347,151
Other Services [Member] | Pampa Energia [Member]
Trade and other receivables [Abstract]
Revenues	3,972,826		2,365,465		1,792,010
Trade receivables	906,281		523,735
Other Services [Member] | YPF [Member]
Trade and other receivables [Abstract]
Revenues	4,278,334		4,530,193		3,954,508
Trade receivables	845,134		893,039
Other Services [Member] | Tecpetrol [Member]
Trade and other receivables [Abstract]
Revenues	2,270,548		875,955		176,811
Trade receivables	417,806		87,291
Other Services [Member] | Exxonmobil Exploration [Member]
Trade and other receivables [Abstract]
Revenues	1,633,267		1,854,769		1,682,932
Trade receivables	242,524		243,569
Other Services [Member] | Vista Oil [Member]
Trade and other receivables [Abstract]
Revenues	235,425		0		0
Trade receivables	121,741		26,881
Other Services [Member] | Pluspetrol [Member]
Trade and other receivables [Abstract]
Revenues	2,638,534		2,352,809		$ 1,730,764
Trade receivables	$ 275,192		$ 535,042

[1] Said amount represents the best estimate made by tgs according to what is stated in Note 4.b).

XML

FINANCIAL RISK MANAGEMENT, Credit Risk, Cash and Financial Placement Maturities (Details) - ARS ($) $ in Thousands		Dec. 31, 2022	Dec. 31, 2021
Maturities of financial assets [Abstract]
Financial assets		$ 103,756,309	$ 102,057,859
From 2026 Onwards [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]		0
Cash and Cash Equivalents [Member]
Maturities of financial assets [Abstract]
Financial assets		2,988,946	8,627,004
Cash and Cash Equivalents [Member] | Without Specified Maturity [Member]
Maturities of financial assets [Abstract]
Financial assets		2,988,946	8,627,004
Cash and Cash Equivalents [Member] | With Specified Maturity Over Due [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Over Due [Member] | Until 12-31 Prior Year [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Over Due [Member] | From 01-01 to 03-31 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Over Due [Member] | From 04-01 to 06-30 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Over Due [Member] | From 07-01 to 09-30 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Over Due [Member] | From 10-01 to 12-31 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | From 01-01 to 03-31 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | From 04-01 to 06-30 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | From 07-01 to 09-30 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | From 10-01 to 12-31 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | During 2023 [Member]
Maturities of financial assets [Abstract]
Financial assets			0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | During 2024 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | During 2025 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | During 2026 [Member]
Maturities of financial assets [Abstract]
Financial assets		0
Cash and Cash Equivalents [Member] | With Specified Maturity Non-Due [Member] | From 2027 Onwards [Member]
Maturities of financial assets [Abstract]
Financial assets		0
Cash and Cash Equivalents [Member] | With Specified Maturity [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Other Financial Assets [Member]
Maturities of financial assets [Abstract]
Financial assets		79,453,351	69,569,112
Other Financial Assets [Member] | Without Specified Maturity [Member]
Maturities of financial assets [Abstract]
Financial assets		39,289,630	24,456,434
Other Financial Assets [Member] | With Specified Maturity Over Due [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Other Financial Assets [Member] | With Specified Maturity Over Due [Member] | Until 12-31 Prior Year [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Other Financial Assets [Member] | With Specified Maturity Over Due [Member] | From 01-01 to 03-31 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Other Financial Assets [Member] | With Specified Maturity Over Due [Member] | From 04-01 to 06-30 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Other Financial Assets [Member] | With Specified Maturity Over Due [Member] | From 07-01 to 09-30 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Other Financial Assets [Member] | With Specified Maturity Over Due [Member] | From 10-01 to 12-31 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member]
Maturities of financial assets [Abstract]
Financial assets		40,163,721	45,112,678
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | From 01-01 to 03-31 [Member]
Maturities of financial assets [Abstract]
Financial assets		192	1,350
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | From 04-01 to 06-30 [Member]
Maturities of financial assets [Abstract]
Financial assets		192	1,143
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | From 07-01 to 09-30 [Member]
Maturities of financial assets [Abstract]
Financial assets		1,054	732
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | From 10-01 to 12-31 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	497
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | During 2023 [Member]
Maturities of financial assets [Abstract]
Financial assets			45,108,956
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | During 2024 [Member]
Maturities of financial assets [Abstract]
Financial assets		40,162,283	0
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | During 2025 [Member]
Maturities of financial assets [Abstract]
Financial assets		0	0
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | During 2026 [Member]
Maturities of financial assets [Abstract]
Financial assets		0
Other Financial Assets [Member] | With Specified Maturity Non-Due [Member] | From 2027 Onwards [Member]
Maturities of financial assets [Abstract]
Financial assets		0
Other Financial Assets [Member] | With Specified Maturity [Member]
Maturities of financial assets [Abstract]
Financial assets		40,163,721	45,112,678
Credits [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	21,446,533	24,119,885
Credits [Member] | Without Specified Maturity [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	40,389	73,421
Credits [Member] | With Specified Maturity Over Due [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	1,680,146	3,722,641
Credits [Member] | With Specified Maturity Over Due [Member] | Until 12-31 Prior Year [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	173,477	264,751
Credits [Member] | With Specified Maturity Over Due [Member] | From 01-01 to 03-31 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	8,167	0
Credits [Member] | With Specified Maturity Over Due [Member] | From 04-01 to 06-30 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	26,427	0
Credits [Member] | With Specified Maturity Over Due [Member] | From 07-01 to 09-30 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	22,530	81,875
Credits [Member] | With Specified Maturity Over Due [Member] | From 10-01 to 12-31 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	1,449,545	3,376,015
Credits [Member] | With Specified Maturity Non-Due [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	19,725,998	20,323,823
Credits [Member] | With Specified Maturity Non-Due [Member] | From 01-01 to 03-31 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	19,536,293	19,607,691
Credits [Member] | With Specified Maturity Non-Due [Member] | From 04-01 to 06-30 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	113,994	587,968
Credits [Member] | With Specified Maturity Non-Due [Member] | From 07-01 to 09-30 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	57,932	112,848
Credits [Member] | With Specified Maturity Non-Due [Member] | From 10-01 to 12-31 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	3,753	939
Credits [Member] | With Specified Maturity Non-Due [Member] | During 2023 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]		14,377
Credits [Member] | With Specified Maturity Non-Due [Member] | During 2024 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	14,026	0
Credits [Member] | With Specified Maturity Non-Due [Member] | During 2025 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	0	0
Credits [Member] | With Specified Maturity Non-Due [Member] | During 2026 [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	0
Credits [Member] | With Specified Maturity Non-Due [Member] | From 2027 Onwards [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	0
Credits [Member] | With Specified Maturity [Member]
Maturities of financial assets [Abstract]
Financial assets	[1],[2]	$ 21,406,144	$ 24,046,464

[1] Includes financial assets recorded in trade receivables and other receivables, excluding allowance for doubtful accounts.Includes financial assets recorded in trade receivables and other receivables, excluding allowance for doubtful accounts.

[2] The total amount of the receivables without specified maturity is recorded in Non-current assets.The total amount of the receivables without specified maturity is recorded in Non-current assets.

XML

FINANCIAL RISK MANAGEMENT, Liquidity Risk (Details) - ARS ($) $ in Thousands		Dec. 31, 2022		Dec. 31, 2021
Maturities of financial liabilities [Abstract]
Loans	[2]	$ 94,614,065	[1]	$ 102,421,012
During 2024 [Member]
Maturities of financial liabilities [Abstract]
Loans		84,503,312
During 2025 [Member]
Maturities of financial liabilities [Abstract]
Loans		770,228
From 2027 Onwards [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Liquidity Risk [Member]
Maturities of financial liabilities [Abstract]
Loans		105,396,831		123,763,922
Other financial liabilities		12,858,263		14,728,396
Finance leases		4,901,101		7,032,376
Liquidity Risk [Member] | Without Specified Maturity [Member]
Maturities of financial liabilities [Abstract]
Loans		0		0
Other financial liabilities		0		0
Finance leases		0		0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member]
Maturities of financial liabilities [Abstract]
Loans		0		0
Other financial liabilities		231,917		579,275
Finance leases		133,549		150,834
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | Until 12-31-2021 [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Other financial liabilities		230,673
Finance leases		0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | From 01-01-22 to 03-31-22 [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Other financial liabilities		311
Finance leases		0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | From 04-01-22 to 06-30-22 [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Other financial liabilities		311
Finance leases		0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | From 07-01-22 to 09-30-22 [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Other financial liabilities		311
Finance leases		0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | From 10-01-22 to 12-31-22 [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Other financial liabilities		311
Finance leases		133,549
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | Until 12-31-2020 [Member]
Maturities of financial liabilities [Abstract]
Loans				0
Other financial liabilities				576,851
Finance leases				0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | From 01-01-21 to 03-31-21 [Member]
Maturities of financial liabilities [Abstract]
Loans				0
Other financial liabilities				606
Finance leases				0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | From 04-01-21 to 06-30-21 [Member]
Maturities of financial liabilities [Abstract]
Loans				0
Other financial liabilities				606
Finance leases				0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | From 07-01-21 to 09-30-21 [Member]
Maturities of financial liabilities [Abstract]
Loans				0
Other financial liabilities				606
Finance leases				0
Liquidity Risk [Member] | With Specified Maturity Over Due [Member] | From 10-01-21 to 12-31-21 [Member]
Maturities of financial liabilities [Abstract]
Loans				0
Other financial liabilities				606
Finance leases				150,834
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member]
Maturities of financial liabilities [Abstract]
Loans		105,396,831		123,763,922
Other financial liabilities		12,626,346		14,149,121
Finance leases		4,767,552		6,881,542
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 01-01-22 to 03-31-22 [Member]
Maturities of financial liabilities [Abstract]
Loans				82,329
Other financial liabilities				14,066,957
Finance leases				374,170
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 04-01-22 to 06-30-22 [Member]
Maturities of financial liabilities [Abstract]
Loans				3,376,545
Other financial liabilities				82,164
Finance leases				374,170
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 07-01-22 to 09-30-22 [Member]
Maturities of financial liabilities [Abstract]
Loans				0
Other financial liabilities				0
Finance leases				374,170
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 10-01-22 to 12-31-22 [Member]
Maturities of financial liabilities [Abstract]
Loans				3,376,545
Other financial liabilities				0
Finance leases				374,170
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 01-01-23 to 03-31-23 [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Other financial liabilities		12,547,599
Finance leases		331,289
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 04-01-23 to 06-30-23 [Member]
Maturities of financial liabilities [Abstract]
Loans		3,316,733
Other financial liabilities		78,747
Finance leases		331,289
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 07-01-23 to 09-30-23 [Member]
Maturities of financial liabilities [Abstract]
Loans		1,541,798
Other financial liabilities		0
Finance leases		331,289
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 10-01-23 to 12-31-23 [Member]
Maturities of financial liabilities [Abstract]
Loans		2,989,575
Other financial liabilities		0
Finance leases		331,289
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | During 2024 [Member]
Maturities of financial liabilities [Abstract]
Loans		5,979,150
Other financial liabilities		0
Finance leases		1,325,334
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | During 2025 [Member]
Maturities of financial liabilities [Abstract]
Loans		91,569,575
Other financial liabilities		0
Finance leases		1,325,334
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | During 2026 [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Other financial liabilities		0
Finance leases		791,728
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 2027 Onwards [Member]
Maturities of financial liabilities [Abstract]
Loans		0
Other financial liabilities		0
Finance leases		0
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | From 2026 Onwards [Member]
Maturities of financial liabilities [Abstract]
Loans				0
Other financial liabilities				0
Finance leases				894,210
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | During 2023 [Member]
Maturities of financial liabilities [Abstract]
Loans				6,753,090
Other financial liabilities				0
Finance leases				1,496,884
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | During 2024 [Member]
Maturities of financial liabilities [Abstract]
Loans				6,753,090
Other financial liabilities				0
Finance leases				1,496,884
Liquidity Risk [Member] | With Specified Maturity Non-Due [Member] | During 2025 [Member]
Maturities of financial liabilities [Abstract]
Loans				103,422,323
Other financial liabilities				0
Finance leases				1,496,884
Liquidity Risk [Member] | With Specified Maturity [Member]
Maturities of financial liabilities [Abstract]
Loans		105,396,831		123,763,922
Other financial liabilities		12,858,263		14,728,396
Finance leases		$ 4,901,101		$ 7,032,376

[1] As of December 31, 2022 and 2021, it is net of Notes repurchase of Ps 5,257,400 and Ps. 4,484,852, respectively.

[2] Net of issuance expenses of Ps. 30,105 and Ps. 102,623 as of December 31, 2022 and 2021, respectively.

XML

FINANCIAL RISK MANAGEMENT, Capital Management Risk (Details) - ARS ($) $ in Thousands		12 Months Ended
		Dec. 31, 2022		Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
FINANCIAL RISK MANAGEMENT [Abstract]
Total debt (Note 13)	[2]	$ 94,614,065	[1]	$ 102,421,012
Total equity		267,224,289		234,906,487	$ 194,134,175	$ 192,471,402
Total capital		$ 361,838,354		$ 337,327,499
Gearing Ratio		0.26%		0.30%

[1] As of December 31, 2022 and 2021, it is net of Notes repurchase of Ps 5,257,400 and Ps. 4,484,852, respectively.

[2] Net of issuance expenses of Ps. 30,105 and Ps. 102,623 as of December 31, 2022 and 2021, respectively.

XML

FINANCIAL RISK MANAGEMENT, Financial Instrument Categories (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
CURRENT ASSETS [Abstract]
Total current assets	$ 63,579,127	$ 58,321,130
NON-CURRENT ASSETS [Abstract]
Total non-current assets	40,177,182	43,736,729
Total assets	103,756,309	102,057,859
CURRENT LIABILITIES [Abstract]
Total current liabilities	16,884,944	17,101,742
NON-CURRENT LIABILITIES [Abstract]
Total non-current liabilities	90,694,136	100,121,274
Total liabilities	107,579,080	117,223,016
Trade Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	10,524,936	11,820,683
Derivative Financial Instruments [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		82,329
Loans [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	3,919,929	2,299,738
Payroll and Social Security Taxes Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	2,153,524	2,279,022
Other Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	286,555	619,970
Loans [Member]
NON-CURRENT LIABILITIES [Abstract]
Total non-current liabilities	90,694,136	100,121,274
Financial Liabilities at Fair Value [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	0	82,329
NON-CURRENT LIABILITIES [Abstract]
Total non-current liabilities	0	0
Total liabilities	0	82,329
Financial Liabilities at Fair Value [Member] | Trade Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	0	0
Financial Liabilities at Fair Value [Member] | Derivative Financial Instruments [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		82,329
Financial Liabilities at Fair Value [Member] | Loans [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	0	0
Financial Liabilities at Fair Value [Member] | Payroll and Social Security Taxes Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	0	0
Financial Liabilities at Fair Value [Member] | Other Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	0	0
Financial Liabilities at Fair Value [Member] | Loans [Member]
NON-CURRENT LIABILITIES [Abstract]
Total non-current liabilities	0	0
Other Financial Liabilities [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	16,884,944	17,019,413
NON-CURRENT LIABILITIES [Abstract]
Total non-current liabilities	90,694,136	100,121,274
Total liabilities	107,579,080	117,140,687
Other Financial Liabilities [Member] | Trade Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	10,524,936	11,820,683
Other Financial Liabilities [Member] | Derivative Financial Instruments [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		0
Other Financial Liabilities [Member] | Loans [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	3,919,929	2,299,738
Other Financial Liabilities [Member] | Payroll and Social Security Taxes Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	2,153,524	2,279,022
Other Financial Liabilities [Member] | Other Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities	286,555	619,970
Other Financial Liabilities [Member] | Loans [Member]
NON-CURRENT LIABILITIES [Abstract]
Total non-current liabilities	90,694,136	100,121,274
Trade Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets	16,939,295	20,693,854
Other Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets	4,359,818	3,151,559
NON-CURRENT ASSETS [Abstract]
Total non-current assets	14,899	16,330
Financial Assets at Amortized Cost [Member]
CURRENT ASSETS [Abstract]
Total current assets	1,438	3,721
NON-CURRENT ASSETS [Abstract]
Total non-current assets	40,162,283	43,720,399
Financial Assets at Fair Value Through Profit or Loss [Member]
CURRENT ASSETS [Abstract]
Total current assets	39,289,630	25,844,992
Cash and Cash Equivalents [Member]
CURRENT ASSETS [Abstract]
Total current assets	2,988,946	8,627,004
Financial Assets at Fair Value [Member]
CURRENT ASSETS [Abstract]
Total current assets	41,955,444	34,042,964
NON-CURRENT ASSETS [Abstract]
Total non-current assets	0	0
Total assets	41,955,444	34,042,964
Financial Assets at Fair Value [Member] | Trade Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets	0	0
Financial Assets at Fair Value [Member] | Other Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets	0	0
NON-CURRENT ASSETS [Abstract]
Total non-current assets	0	0
Financial Assets at Fair Value [Member] | Financial Assets at Amortized Cost [Member]
CURRENT ASSETS [Abstract]
Total current assets	0	0
NON-CURRENT ASSETS [Abstract]
Total non-current assets	0	0
Financial Assets at Fair Value [Member] | Financial Assets at Fair Value Through Profit or Loss [Member]
CURRENT ASSETS [Abstract]
Total current assets	39,289,630	25,844,992
Financial Assets at Fair Value [Member] | Cash and Cash Equivalents [Member]
CURRENT ASSETS [Abstract]
Total current assets	2,665,814	8,197,972
Financial assets at Amortized Cost [Member]
CURRENT ASSETS [Abstract]
Total current assets	21,623,683	24,278,166
NON-CURRENT ASSETS [Abstract]
Total non-current assets	40,177,182	43,736,729
Total assets	61,800,865	68,014,895
Financial assets at Amortized Cost [Member] | Trade Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets	16,939,295	20,693,854
Financial assets at Amortized Cost [Member] | Other Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets	4,359,818	3,151,559
NON-CURRENT ASSETS [Abstract]
Total non-current assets	14,899	16,330
Financial assets at Amortized Cost [Member] | Financial Assets at Amortized Cost [Member]
CURRENT ASSETS [Abstract]
Total current assets	1,438	3,721
NON-CURRENT ASSETS [Abstract]
Total non-current assets	40,162,283	43,720,399
Financial assets at Amortized Cost [Member] | Financial Assets at Fair Value Through Profit or Loss [Member]
CURRENT ASSETS [Abstract]
Total current assets	0	0
Financial assets at Amortized Cost [Member] | Cash and Cash Equivalents [Member]
CURRENT ASSETS [Abstract]
Total current assets	$ 323,132	$ 429,032

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FINANCIAL RISK MANAGEMENT, Fair Value Measurement Hierarchy and Estimates (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Financial assets at fair value [Abstract]
Financial assets at fair value through profit or loss	$ 39,289,630	$ 25,844,992
Financial liabilities at fair value [Abstract]
Derivative financial instruments	0	82,329
Financial liabilities at carrying amount and estimated fair value [Abstract]
Carrying amount	107,579,080	117,223,016
2018 Note [Member]
Financial liabilities at fair value [Abstract]
Total	77,460,798
Financial liabilities at carrying amount and estimated fair value [Abstract]
Carrying amount	84,229,875
Fair Value	77,460,798
Fair Value [Member]
Financial assets at fair value [Abstract]
Cash and cash equivalents	2,665,814	8,197,972
Financial assets at fair value through profit or loss	39,289,630	25,844,992
Total	41,955,444	34,042,964
Financial liabilities at fair value [Abstract]
Derivative financial instruments		82,329
Total		82,329
Financial liabilities at carrying amount and estimated fair value [Abstract]
Fair Value		82,329
Fair Value [Member] | Level 1 [Member]
Financial assets at fair value [Abstract]
Cash and cash equivalents	2,665,814	8,197,972
Financial assets at fair value through profit or loss	39,289,630	25,844,992
Total	41,955,444	34,042,964
Financial liabilities at fair value [Abstract]
Derivative financial instruments		82,329
Total		82,329
Financial liabilities at carrying amount and estimated fair value [Abstract]
Fair Value		82,329
Fair Value [Member] | Level 2 [Member]
Financial assets at fair value [Abstract]
Cash and cash equivalents	0	0
Financial assets at fair value through profit or loss	0	0
Total	0	0
Financial liabilities at fair value [Abstract]
Derivative financial instruments		0
Total		0
Financial liabilities at carrying amount and estimated fair value [Abstract]
Fair Value		0
Fair Value [Member] | Level 3 [Member]
Financial assets at fair value [Abstract]
Cash and cash equivalents	0	0
Financial assets at fair value through profit or loss	0	0
Total	$ 0	0
Financial liabilities at fair value [Abstract]
Derivative financial instruments		0
Total		0
Financial liabilities at carrying amount and estimated fair value [Abstract]
Fair Value		$ 0

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REGULATORY FRAMEWORK, General Framework of the Natural Gas Transportation Segment (Details) $ in Thousands		12 Months Ended
	Jan. 19, 2022 stage	Dec. 31, 2022 ARS ($) Installment	Mar. 01, 2022	Apr. 02, 2021	Apr. 01, 2019	Oct. 02, 2018	Sep. 04, 2018	Apr. 01, 2018	Dec. 01, 2017	Apr. 02, 2017	Mar. 30, 2017
General aspects [Abstract]
Original license period		35 years
License period, renewal		10 years
License period, after renewal		45 years
Tariff situation [Abstract]
Natural gas transportation tariffs period, condition one		semiannually
Natural gas transportation tariffs period, condition two		5 years
Conversion rate of exchange for tariffs		1
Number of years for negotiations under transitional agreement		17 years
Transitional Agreement [Abstract]
Percentage of increase in tariff on service for natural gas transportation					26.00%				81.10%	64.20%	214.20%
Percentage of increase in tariff on access and use									29.70%		37.00%
Investment plan period		5 years
Five Year Plan investment amount | $		$ 6,786,543
Number of installments tariff increase granted | Installment		3
Percentage of tariff increase on public service of Natural Gas Transportation and CAU								50.00%
Percentage of increase in tariff			60.00%	58.60%		19.70%	30.00%
Period of natural gas transportation and distribution tariff remain unadjusted		180 days
Period for natural gas transportation and distribution tariffs extended		180 days
Additional period for transitory tariffs freeze		90 days
Transitory tariff adjustment applied stages | stage	2
Transitory tariff adjustment percentage	106.00%
Top of Range [Member]
Transitional Agreement [Abstract]
Tariff review period		2 years

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REGULATORY FRAMEWORK, General Framework for Non-Regulated Segments (Details)					9 Months Ended	12 Months Ended
	Sep. 30, 2022 $ / Ton	Oct. 19, 2020 ARS ($)	Dec. 01, 2011 $ / m³	Nov. 30, 2011 $ / m³	Dec. 31, 2021 ARS ($)	Dec. 31, 2022 ARS ($) $ / bbl $ / m³	Dec. 31, 2017 ARS ($)	Dec. 23, 2019	Sep. 03, 2018 USD ($)
Domestic market [Abstract]
Period of maximum reference prices for commercialization of liquefied petroleum gas unchanged						180 days
Increase in price of liquefied petroleum gas		$ 10,885,000			$ 12,626,600
Increase in ordered price of liquefied petroleum gas | $ / Ton	18,375.49
Increase in price of propane gas per ton							$ 1,267,000
Increase in price of propane gas per ton depending on customer							2,832,000
Subsidies receivable from government					$ 2,427,450,000	$ 3,768,159,000
Foreign market [Abstract]
Capped amount of each dollar of the tax base or the official FOB price									$ 4
Rate applicable to hydrocarbons								8.00%
Barrel price, condition one | $ / bbl						45
Barrel price, condition two | $ / bbl						60
Tax rate for barrel price below US$45						0.00%
Tax rate for barrel price equal or higher than US$60						8.00%
Tariff charge paid (per cubic meter) | $ / m³						0.0492
Tariff charge (per cubic meter) | $ / m³			0.405	0.0492
Bottom of Range [Member]
Foreign market [Abstract]
Applicable tax rate on export of oil and gas products						0.00%
Top of Range [Member]
Foreign market [Abstract]
Applicable tax rate on export of oil and gas products						8.00%
Propane [Member]
Domestic market [Abstract]
Increase in price of propane gas per ton							1,941,200
Increase in price of propane gas per ton depending on customer							$ 3,964,000
Foreign market [Abstract]
Export duty percentage									12.00%
Butane [Member]
Foreign market [Abstract]
Export duty percentage									12.00%
Natural Gasoline [Member]
Foreign market [Abstract]
Export duty percentage									12.00%

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ASSETS AND LIABILITIES IN FORREIGN CURRENCY (Details) $ in Thousands, $ in Thousands		Dec. 31, 2022 ARS ($) $ / $ $ / €	Dec. 31, 2022 USD ($) $ / $ $ / €	Dec. 31, 2022 EUR (€) $ / $ $ / €	Dec. 31, 2021 ARS ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2021 EUR (€)
CURRENT ASSETS [Abstract]
Total current assets		$ 63,579,127			$ 58,321,130
NON-CURRENT ASSETS [Abstract]
Total non-current assets		40,177,182			43,736,729
Total assets		103,756,309			102,057,859
CURRENT LIABILITIES [Abstract]
Total current liabilities		16,884,944			17,101,742
NON CURRENT LIABILITIES [Abstract]
Total non-current liabilities		90,694,136			100,121,274
TOTAL LIABILITIES		107,579,080			117,223,016
Public and private debt bonds		27,013,330
Time deposits		865,009
Trade Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		10,524,936			11,820,683
Loans [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		3,919,929			2,299,738
Loans [Member]
NON CURRENT LIABILITIES [Abstract]
Total non-current liabilities		$ 90,694,136			100,121,274
Euro [Member]
NON CURRENT LIABILITIES [Abstract]
Exchange rate (in Ps. per dollars) | $ / €	[1]	189.916	189.916	189.916
Euro [Member] | Loans [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		$ 54,413		€ 287	0		€ 0
Cash and Cash Equivalents [Member]
CURRENT ASSETS [Abstract]
Total current assets		2,988,946			8,627,004
Financial Assets at Amortized Cost [Member]
CURRENT ASSETS [Abstract]
Total current assets		1,438			3,721
NON-CURRENT ASSETS [Abstract]
Total non-current assets		40,162,283			43,720,399
Trade Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets		16,939,295			20,693,854
Other Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets		4,359,818			3,151,559
NON-CURRENT ASSETS [Abstract]
Total non-current assets		14,899			16,330
Foreign Currency [Member]
CURRENT ASSETS [Abstract]
Total current assets		43,279,461	$ 244,572		26,646,033	$ 133,429
NON-CURRENT ASSETS [Abstract]
Total non-current assets		40,162,283	226,957		43,718,092	218,917
Total assets		83,441,744	471,529		70,364,125	352,346
Foreign Currency [Member] | U.S. Dollars [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		10,713,636	60,474		9,864,599	49,300
NON CURRENT LIABILITIES [Abstract]
Total non-current liabilities		92,484,497	522,039		100,121,274	500,377
TOTAL LIABILITIES		103,198,133	582,513		109,985,873	549,677
Foreign Currency [Member] | U.S. Dollars [Member] | Trade Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		$ 6,848,120	$ 38,655		7,564,861	37,807
NON CURRENT LIABILITIES [Abstract]
Exchange rate (in Ps. per dollars) | $ / $	[1]	177.16	177.16	177.16
Foreign Currency [Member] | U.S. Dollars [Member] | Loans [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		$ 3,865,516	$ 21,819		2,299,738	11,493
NON CURRENT LIABILITIES [Abstract]
Exchange rate (in Ps. per dollars) | $ / $	[1]	177.16	177.16	177.16
Foreign Currency [Member] | U.S. Dollars [Member] | Loans [Member]
NON CURRENT LIABILITIES [Abstract]
Total non-current liabilities		$ 90,694,136	$ 511,933		100,121,274	500,377
Exchange rate (in Ps. per dollars) | $ / $	[1]	177.16	177.16	177.16
Foreign Currency [Member] | U.S. Dollars [Member] | Contract Liabilities [Member]
NON CURRENT LIABILITIES [Abstract]
Total non-current liabilities		$ 1,790,361	$ 10,106		0	0
Exchange rate (in Ps. per dollars) | $ / $	[1]	177.16	177.16	177.16
Foreign Currency [Member] | Euro [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		$ 136,456		€ 719,000	0		0
NON CURRENT LIABILITIES [Abstract]
TOTAL LIABILITIES		136,456		719,000			0
Foreign Currency [Member] | Euro [Member] | Trade Payables [Member]
CURRENT LIABILITIES [Abstract]
Total current liabilities		$ 82,043		€ 432,000	0		€ 0
NON CURRENT LIABILITIES [Abstract]
Exchange rate (in Ps. per dollars) | $ / €	[1]	189.916	189.916	189.916
Foreign Currency [Member] | Cash and Cash Equivalents [Member]
CURRENT ASSETS [Abstract]
Total current assets		$ 285,436	$ 1,613		301,949	1,512
NON CURRENT LIABILITIES [Abstract]
Exchange rate (in Ps. per dollars) | $ / $	[2]	176.96	176.96	176.96
Foreign Currency [Member] | Financial Assets at Amortized Cost [Member]
NON-CURRENT ASSETS [Abstract]
Total non-current assets	[3]	$ 40,162,283	$ 226,957		43,718,092	218,917
NON CURRENT LIABILITIES [Abstract]
Exchange rate (in Ps. per dollars) | $ / $	[2],[3]	176.96	176.96	176.96
Foreign Currency [Member] | Financial Assets at Fair Value Through Profit or Loss [Member]
CURRENT ASSETS [Abstract]
Total current assets	[4]	$ 31,295,730	$ 176,852		13,084,872	65,522
NON CURRENT LIABILITIES [Abstract]
Exchange rate (in Ps. per dollars) | $ / $	[2],[4]	176.96	176.96	176.96
Foreign Currency [Member] | Trade Receivables [Member]
CURRENT ASSETS [Abstract]
Total current assets		$ 11,698,295	$ 66,107		$ 13,259,212	$ 66,395
NON CURRENT LIABILITIES [Abstract]
Exchange rate (in Ps. per dollars) | $ / $	[2]	176.96	176.96	176.96

[1] Sell exchange rate at the end of fiscal year

[2] Buy exchange rate at the end of fiscal year

[3] Includes time deposits Dólar Linked for Ps. 865,009.

[4] Includes public and private debt bonds Dólar Linked for Ps. 27,013,330.

XML

COMMON STOCK AND DIVIDENDS, Common Stock Structure and Shares' Public Offer (Details)	12 Months Ended
	Dec. 31, 2022 Vote $ / shares shares	Dec. 31, 2021 Vote $ / shares shares	Dec. 31, 2020 Vote $ / shares shares
Common stock structure and shares [Abstract]
Outstanding shares (in shares)	752,761,058	752,761,058	752,761,058
Number of shares represents for each share on New York Stock Exchange (in shares)	5
Class "A" [Member]
Common stock structure and shares [Abstract]
Outstanding shares (in shares)	405,192,594	405,192,594	405,192,594
Face value common shares class (in pesos per share) | $ / shares	$ 1	$ 1	$ 1
Number of votes for common stock | Vote	1	1	1
Class "B" [Member]
Common stock structure and shares [Abstract]
Outstanding shares (in shares)	347,568,464	347,568,464	347,568,464
Face value common shares class (in pesos per share) | $ / shares	$ 1	$ 1	$ 1
Number of votes for common stock | Vote	1	1	1
Common Stock [Member]
Common stock structure and shares [Abstract]
Shares issued (in shares)	794,495,283	794,495,283	794,495,283
Common Stock [Member] | Class "A" [Member]
Common stock structure and shares [Abstract]
Shares issued (in shares)	405,192,594	405,192,594	405,192,594
Common Stock [Member] | Class "B" [Member]
Common stock structure and shares [Abstract]
Shares issued (in shares)	389,302,689	389,302,689	389,302,689
Treasury Shares [Member]
Common stock structure and shares [Abstract]
Shares issued (in shares)	41,734,225	41,734,225	41,734,225
Face value common shares class (in pesos per share) | $ / shares	$ 1	$ 1	$ 1
Treasury Shares [Member] | Class "A" [Member]
Common stock structure and shares [Abstract]
Shares issued (in shares)	0	0	0
Treasury Shares [Member] | Class "B" [Member]
Common stock structure and shares [Abstract]
Shares issued (in shares)	41,734,225	41,734,225	41,734,225

XML

COMMON STOCK AND DIVIDENDS, Acquisition of Treasury Shares (Details) - ARS ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Aug. 21, 2020	Mar. 06, 2020
Acquisition of treasury shares [Abstract]
Maximum amount invested for shares repurchase program				$ 3,000,000	$ 2,500,000
Acquisition cost of treasury shares	$ 10,924,539	$ 10,924,539
Trading premium on treasury shares	3,169,112	3,169,112
Treasury Shares [Member]
Acquisition of treasury shares [Abstract]
Acquisition cost of treasury shares	10,924,539	$ 10,924,539	$ 10,924,539
Trading premium on treasury shares	$ 3,169,112

XML

COMMON STOCK AND DIVIDENDS, Restrictions on Distribution of Retained Earnings (Details)	12 Months Ended
	Dec. 31, 2022
Restrictions on distribution of retained earnings [Abstract]
Percentage of legal reserve of net income	5.00%
Percentage of aggregate reserve	20.00%

XML

LEGAL CLAIMS AND OTHER MATTERS (Details) $ in Thousands			12 Months Ended	24 Months Ended
	Jun. 04, 2021 Extension	Oct. 09, 2008	Dec. 31, 2022 ARS ($)	Jun. 30, 2011 ARS ($)	Dec. 31, 2021 ARS ($)	Mar. 31, 2017 ARS ($)	May 24, 2013 ARS ($)
LEGAL CLAIMS AND OTHER MATTERS [Abstract]
Provision amount on turnover tax			$ 1,657,400		$ 2,210,700
Validity period of precautionary measure			6 months
Extended Validity Period of Precautionary Measure			6 months
Remaining term of validity period of precautionary measure			2 months 9 days
Number of extensions obtained | Extension	12
Increase in tariff percentage		20.00%
Receivables from income taxes and value added tax							$ 102,500
Claim amount for the omission as agent of withholding and collection of turnover tax				$ 4,900
Canceled partial debt claim amount						$ 2,900
Provision amount on turnover tax withholding			$ 0		0
Provision amount on environmental matters			58,500		92,300
Provision for other matters			$ 77,400		$ 221,500

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BALANCES AND TRANSACTIONS WITH RELATED COMPANIES (Details) $ in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2022 ARS ($)		Dec. 31, 2021 ARS ($)		Dec. 31, 2020 ARS ($)	Dec. 31, 2022 USD ($)
Technical, financial and operational assistance agreement [abstract]
Compensation for key management member		$ 427,015		$ 400,832		$ 406,894
Balances and transactions with related parties [Abstract]
Accounts receivable		1,330,471		695,684
Accounts payable		4,935,175		6,898,037
Financial assets at fair value through profit or loss		39,289,630		25,844,992
Costs [Abstract]
Gas purchase and others		5,826,231		5,628,181		470,636
Compensation for technical assistance		3,067,198		4,250,358		4,205,901
Revenue for administrative services		0		277		411
Financial Results [Abstract]
Interest expense		162		568,315		712,528
Interest gain / Gain / (loss) on fair value		96,408		484,082
Selling expenses	[1]	31,059		2,277
Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		1,769,981		2,007,858		2,893,304
Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		3,583,230		4,996,215		3,087,152
Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		4,044,658		2,446,927		1,892,020
Private Debt Bonds with Related Parties [Member]
Balances and transactions with related parties [Abstract]
Financial assets at fair value through profit or loss		2,570,796		1,388,558
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.) [Member]
Balances and transactions with related parties [Abstract]
Accounts receivable		19,695		24,165
Accounts payable		17,518		35,932
Costs [Abstract]
Gas purchase and others		0		0		0
Compensation for technical assistance		0		0		0
Revenue for administrative services		0		0		0
Financial Results [Abstract]
Interest expense		0		0		0
Interest gain / Gain / (loss) on fair value		0		0
Selling expenses	[1]	0		0
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.) [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		298,568		289,761		331,583
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.) [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		0
Comercializadora e Inversora S.A. (previously Pampa Comercializadora S.A.) [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		0
CT Barragan S.A. [Member]
Balances and transactions with related parties [Abstract]
Accounts receivable		4,294		7,385
Accounts payable		0		0
Costs [Abstract]
Gas purchase and others		0		0
Compensation for technical assistance		0		0
Revenue for administrative services		0		0
Financial Results [Abstract]
Interest expense		0		0
Interest gain / Gain / (loss) on fair value		96,408		484,082
Selling expenses	[1]	0		0
CT Barragan S.A. [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0
CT Barragan S.A. [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0
CT Barragan S.A. [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		17,459		26,659
CT Barragan S.A. [Member] | Private Debt Bonds with Related Parties [Member]
Balances and transactions with related parties [Abstract]
Financial assets at fair value through profit or loss		$ 2,570,796		1,388,558
Accrue annual rate		4.00%					4.00%
SACDE [Member]
Balances and transactions with related parties [Abstract]
Accounts receivable		$ 2,227		0
Accounts payable		0		0
Other receivables				3,318,934
Costs [Abstract]
Gas purchase and others		0		0
Compensation for technical assistance		0		0
Revenue for administrative services		0		0
Financial Results [Abstract]
Interest expense		0		0
Interest gain / Gain / (loss) on fair value		0		0
Selling expenses	[1]	0		0
SACDE [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		51,542
SACDE [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0
SACDE [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		7,203		54,102
Transener S.A. [Member]
Balances and transactions with related parties [Abstract]
Accounts receivable		30		0
Accounts payable		0		61
Costs [Abstract]
Gas purchase and others		0		0		0
Compensation for technical assistance		0		0		0
Revenue for administrative services		0		0		0
Financial Results [Abstract]
Interest expense		0		0		0
Interest gain / Gain / (loss) on fair value		0		0
Selling expenses	[1]	0		0
Transener S.A. [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		0
Transener S.A. [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		0
Transener S.A. [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		417		701		1,034
Fundacion TGS [Member]
Costs [Abstract]
Gas purchase and others		0		0
Compensation for technical assistance		0		0
Revenue for administrative services		0		0
Financial Results [Abstract]
Interest expense		0		0
Interest gain / Gain / (loss) on fair value		0		0
Selling expenses	[1]	31,059		2,277
Fundacion TGS [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0
Fundacion TGS [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0
Fundacion TGS [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0
Petrolera Entre Lomas S.A. [Member]
Costs [Abstract]
Gas purchase and others						0
Compensation for technical assistance						0
Revenue for administrative services						0
Financial Results [Abstract]
Interest expense						0
Petrolera Entre Lomas S.A. [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						7,277
Petrolera Entre Lomas S.A. [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						0
Petrolera Entre Lomas S.A. [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						26,268
Oleoductos del Valle S.A. [Member]
Costs [Abstract]
Gas purchase and others						0
Compensation for technical assistance						0
Revenue for administrative services						0
Financial Results [Abstract]
Interest expense						0
Oleoductos del Valle S.A. [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						75,765
Oleoductos del Valle S.A. [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						0
Oleoductos del Valle S.A. [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						0
Central Termica Piedrabuena S.A. [Member]
Costs [Abstract]
Gas purchase and others						0
Compensation for technical assistance						0
Revenue for administrative services						0
Financial Results [Abstract]
Interest expense						0
Central Termica Piedrabuena S.A. [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						5,131
Central Termica Piedrabuena S.A. [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						0
Central Termica Piedrabuena S.A. [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues						0
Link [Member]
Balances and transactions with related parties [Abstract]
Accounts receivable		4,683		5,088
Accounts payable		0		0
Costs [Abstract]
Gas purchase and others		0		0		0
Compensation for technical assistance		0		0		0
Revenue for administrative services		0		0		0
Financial Results [Abstract]
Interest expense		0		0		0
Interest gain / Gain / (loss) on fair value		0		0
Selling expenses	[1]	0		0
Link [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		0
Link [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		0
Link [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		46,750		0		57,517
TGU [Member]
Balances and transactions with related parties [Abstract]
Accounts receivable		0		0
Accounts payable		28,199		31,849
Pampa Energia [Member]
Balances and transactions with related parties [Abstract]
Accounts receivable	[2]	1,299,505		659,046
Accounts payable		4,889,458	[2]	6,830,195	[2]		$ 0.5
Financial lease		4,262,215		5,887,648
Costs [Abstract]
Gas purchase and others		5,826,231		5,628,181		470,636
Compensation for technical assistance		3,067,198		4,250,358		4,205,901
Revenue for administrative services		0		0		0
Financial Results [Abstract]
Interest expense		0		568,315		712,528
Interest gain / Gain / (loss) on fair value		0		0
Selling expenses	[1]	$ 0		0
Pampa Energia [Member] | From 12/28/2019 to 12/27/2020 [Member]
Technical, financial and operational assistance agreement [abstract]
Percentage of annual comprehensive income before results and income taxes		6.50%
Pampa Energia [Member] | From 12/28/2020 to 12/27/2021 [Member]
Technical, financial and operational assistance agreement [abstract]
Percentage of annual comprehensive income before results and income taxes		6.00%
Pampa Energia [Member] | From 12/28/2021 to 12/27/2022 [Member]
Technical, financial and operational assistance agreement [abstract]
Percentage of annual comprehensive income before results and income taxes		5.50%
Pampa Energia [Member] | From 12/28/2022 to 12/27/2023 [Member]
Technical, financial and operational assistance agreement [abstract]
Percentage of annual comprehensive income before results and income taxes		5.00%
Pampa Energia [Member] | From 12/28/2023 to 12/27/2024 and onwards [Member]
Technical, financial and operational assistance agreement [abstract]
Percentage of annual comprehensive income before results and income taxes		4.50%
Pampa Energia [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		$ 1,471,413		1,666,555		2,473,548
Pampa Energia [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		3,583,230		4,996,215		3,087,152
Pampa Energia [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		3,972,829		2,365,465		1,807,202
CIESA [Member]
Costs [Abstract]
Gas purchase and others		0		0		0
Compensation for technical assistance		0		0		0
Revenue for administrative services		0		277		411
Financial Results [Abstract]
Interest expense		162		0		0
Interest gain / Gain / (loss) on fair value		0		0
Selling expenses	[1]	0		0
CIESA [Member] | Natural Gas Transportation [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		0
CIESA [Member] | Production and Commercialization of Liquids [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		0
CIESA [Member] | Other Services [Member]
Detail of Significant Transactions with Related Parties [abstract]
Revenues		0		0		$ 0
CIESA [Member] | Pampa Energia [Member]
Balances and transactions with related parties [Abstract]
Accounts receivable		37		0
Accounts payable		$ 0		$ 0

[1] Corresponds to donations expenses.Corresponds to donations expenses.

[2] Accounts payable includes Ps. 4,262,215 and Ps. 5,887,648 corresponding to the financial leasing recorded as “Loans” as of December 31, 2022 and 2021, respectively.

XML

CONTRACTUAL OBLIGATIONS (Details) $ in Thousands	Dec. 31, 2022 ARS ($) $ / $
Contractual commitments [abstract]
Contractual commitments	$ 132,815,392
Due Less than One Year [Member]
Contractual commitments [abstract]
Contractual commitments	133,549
As of 12/31/2022 [Member]
Contractual commitments [abstract]
Contractual commitments	25,462,684
From 1/01/2023 to 12/31/2023 [Member]
Contractual commitments [abstract]
Contractual commitments	13,532,522
From 01/01/2024 to 12/31/2024 [Member]
Contractual commitments [abstract]
Contractual commitments	92,894,909
From 1/01/2026 to 12/31/2026 [Member]
Contractual commitments [abstract]
Contractual commitments	791,728
Financial Indebtedness [Member]
Contractual commitments [abstract]
Contractual commitments	$ 109,769,494	[1]
Exchange rate (in Ps. per dollars) | $ / $	177.16
Financial Indebtedness [Member] | Due Less than One Year [Member]
Contractual commitments [abstract]
Contractual commitments	$ 0	[1]
Financial Indebtedness [Member] | As of 12/31/2022 [Member]
Contractual commitments [abstract]
Contractual commitments	7,848,106	[1]
Financial Indebtedness [Member] | From 1/01/2023 to 12/31/2023 [Member]
Contractual commitments [abstract]
Contractual commitments	10,351,813	[1]
Financial Indebtedness [Member] | From 01/01/2024 to 12/31/2024 [Member]
Contractual commitments [abstract]
Contractual commitments	91,569,575	[1]
Financial Indebtedness [Member] | From 1/01/2026 to 12/31/2026 [Member]
Contractual commitments [abstract]
Contractual commitments	0	[1]
Purchase Obligations [Member]
Contractual commitments [abstract]
Contractual commitments	18,144,797	[2]
Purchase Obligations [Member] | Due Less than One Year [Member]
Contractual commitments [abstract]
Contractual commitments	0	[2]
Purchase Obligations [Member] | As of 12/31/2022 [Member]
Contractual commitments [abstract]
Contractual commitments	16,289,422	[2]
Purchase Obligations [Member] | From 1/01/2023 to 12/31/2023 [Member]
Contractual commitments [abstract]
Contractual commitments	1,855,375	[2]
Purchase Obligations [Member] | From 01/01/2024 to 12/31/2024 [Member]
Contractual commitments [abstract]
Contractual commitments	0	[2]
Purchase Obligations [Member] | From 1/01/2026 to 12/31/2026 [Member]
Contractual commitments [abstract]
Contractual commitments	0	[2]
Financial Leasing [Member]
Contractual commitments [abstract]
Contractual commitments	4,901,101
Financial Leasing [Member] | Due Less than One Year [Member]
Contractual commitments [abstract]
Contractual commitments	133,549
Financial Leasing [Member] | As of 12/31/2022 [Member]
Contractual commitments [abstract]
Contractual commitments	1,325,156
Financial Leasing [Member] | From 1/01/2023 to 12/31/2023 [Member]
Contractual commitments [abstract]
Contractual commitments	1,325,334
Financial Leasing [Member] | From 01/01/2024 to 12/31/2024 [Member]
Contractual commitments [abstract]
Contractual commitments	1,325,334
Financial Leasing [Member] | From 1/01/2026 to 12/31/2026 [Member]
Contractual commitments [abstract]
Contractual commitments	$ 791,728

[1] Corresponds to the cancellation of principal and interest of the financial indebtedness. For further information, see Note 13.

[2] Corresponds to purchase of natural gas contracts for the processing of liquids.

XML

ASSOCIATES AND JOINT ARRANGEMENTS (Details)		12 Months Ended
	Nov. 13, 2013 USD ($)	Dec. 31, 2022 ARS ($)	Dec. 31, 2021 ARS ($)	Dec. 31, 2020 ARS ($)	Dec. 29, 2021 ARS ($)
Information about associates and arrangements [Abstract]
Purchase of fixed assets		$ 25,307,541,000	$ 18,794,792,000	$ 22,844,489,000
UT [Member]
Information about associates and arrangements [Abstract]
Guarantee period from the provisional reception of the UT Works		18 months
Link [Member]
Information about associates and arrangements [Abstract]
Percentage of ownership		49.00%
Cash dividend paid					$ 181,984
Link [Member] | Pan American Sur S.A. [Member]
Information about associates and arrangements [Abstract]
Percentage of ownership		20.40%
Percentage of joint ownership		20.40%
Link [Member] | Shell Argentina S.A. [Member]
Information about associates and arrangements [Abstract]
Percentage of ownership		25.50%
Percentage of joint ownership		25.50%
Link [Member] | Wintershall Dea Argentina S.A. [Member]
Information about associates and arrangements [Abstract]
Percentage of joint ownership		5.10%
TGU [Member]
Information about associates and arrangements [Abstract]
Percentage of ownership		49.00%
TGU [Member] | Pampa Energia [Member]
Information about associates and arrangements [Abstract]
Percentage of joint ownership		51.00%
EGS [Member]
Information about associates and arrangements [Abstract]
Percentage of ownership		49.00%
Percentage of joint ownership		51.00%
Purchase of fixed assets	$ 350,000

XML

SUBSEQUENT EVENTS (Details) $ in Millions	Apr. 19, 2023 ARS ($)	Apr. 19, 2023 USD ($)	Apr. 19, 2023 ARS ($)	Apr. 01, 2023	Dec. 31, 2022 USD ($)	Dec. 31, 2018 USD ($)
2018 Note [Member] | Top of Range [Member]
Subsequent Event [Abstract]
Maximum principal amount					$ 1,200,000,000	$ 700,000,000
Subsequent Event [Member]
Subsequent Event [Abstract]
Percentage of transitional tariff increase				95.00%
Increase in legal reserve	$ 1,967
Reserve for capital expenditures, acquisition of treasury shares and dividends			$ 185,004
Subsequent Event [Member] | 2018 Note [Member] | Top of Range [Member]
Subsequent Event [Abstract]
Maximum principal amount		$ 2,000,000,000